Document and Entity Information
Document and Entity Information - USD ($) $ in Billions | 12 Months Ended | ||
Dec. 31, 2023 | Jan. 31, 2024 | Jun. 30, 2023 | |
Document Transition Report | false | ||
Entity File Number | 1-11299 | ||
Document Annual Report | true | ||
Entity Registrant Name | ENTERGY CORPORATION | ||
Entity Central Index Key | 0000065984 | ||
Document Type | 10-K | ||
Document Period End Date | Dec. 31, 2023 | ||
Amendment Flag | false | ||
Document Fiscal Year Focus | 2023 | ||
Document Fiscal Period Focus | FY | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Incorporation, State or Country Code | DE | ||
Entity Address, Address Line One | 639 Loyola Avenue | ||
Entity Address, City or Town | New Orleans | ||
Entity Address, State or Province | LA | ||
Entity Address, Postal Zip Code | 70113 | ||
City Area Code | 504 | ||
Local Phone Number | 576-4000 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Public Float | $ 20.6 | ||
Entity Common Stock, Shares Outstanding | 213,237,552 | ||
Entity Tax Identification Number | 72-1229752 | ||
ICFR Auditor Attestation Flag | true | ||
Document Financial Statement Error Correction [Flag] | false | ||
Auditor Location | New Orleans, Louisiana | ||
Auditor Name | Deloitte & Touche LLP | ||
Auditor Firm ID | 34 | ||
Entergy Arkansas [Member] | |||
Entity File Number | 1-10764 | ||
Entity Registrant Name | ENTERGY ARKANSAS, LLC | ||
Entity Central Index Key | 0000007323 | ||
Entity Incorporation, State or Country Code | TX | ||
Entity Address, Address Line One | 425 West Capitol Avenue | ||
Entity Address, City or Town | Little Rock | ||
Entity Address, State or Province | AR | ||
Entity Address, Postal Zip Code | 72201 | ||
City Area Code | 501 | ||
Local Phone Number | 377-4000 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 83-1918668 | ||
ICFR Auditor Attestation Flag | |||
Document Financial Statement Error Correction [Flag] | false | ||
Entergy Louisiana [Member] | |||
Entity File Number | 1-32718 | ||
Entity Registrant Name | ENTERGY LOUISIANA, LLC | ||
Entity Central Index Key | 0001348952 | ||
Entity Incorporation, State or Country Code | TX | ||
Entity Address, Address Line One | 4809 Jefferson Highway | ||
Entity Address, City or Town | Jefferson | ||
Entity Address, State or Province | LA | ||
Entity Address, Postal Zip Code | 70121 | ||
City Area Code | 504 | ||
Local Phone Number | 576-4000 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 47-4469646 | ||
ICFR Auditor Attestation Flag | |||
Document Financial Statement Error Correction [Flag] | false | ||
Entergy Mississippi [Member] | |||
Entity File Number | 1-31508 | ||
Entity Registrant Name | ENTERGY MISSISSIPPI, LLC | ||
Entity Central Index Key | 0000066901 | ||
Entity Incorporation, State or Country Code | TX | ||
Entity Address, Address Line One | 308 East Pearl Street | ||
Entity Address, City or Town | Jackson | ||
Entity Address, State or Province | MS | ||
Entity Address, Postal Zip Code | 39201 | ||
City Area Code | 601 | ||
Local Phone Number | 368-5000 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 83-1950019 | ||
ICFR Auditor Attestation Flag | |||
Document Financial Statement Error Correction [Flag] | false | ||
Entergy New Orleans [Member] | |||
Entity File Number | 1-35747 | ||
Entity Registrant Name | ENTERGY NEW ORLEANS, LLC | ||
Entity Central Index Key | 0000071508 | ||
Entity Incorporation, State or Country Code | TX | ||
Entity Address, Address Line One | 1600 Perdido Street | ||
Entity Address, City or Town | New Orleans | ||
Entity Address, State or Province | LA | ||
Entity Address, Postal Zip Code | 70112 | ||
City Area Code | 504 | ||
Local Phone Number | 670-3702 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 82-2212934 | ||
ICFR Auditor Attestation Flag | |||
Document Financial Statement Error Correction [Flag] | false | ||
Entergy Texas [Member] | |||
Title of 12(g) Security | Common Stock, no par value | ||
Entity File Number | 1-34360 | ||
Entity Registrant Name | ENTERGY TEXAS, INC. | ||
Entity Central Index Key | 0001427437 | ||
Entity Incorporation, State or Country Code | TX | ||
Entity Address, Address Line One | 2107 Research Forest Drive | ||
Entity Address, City or Town | The Woodlands | ||
Entity Address, State or Province | TX | ||
Entity Address, Postal Zip Code | 77380 | ||
City Area Code | 409 | ||
Local Phone Number | 981-2000 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 61-1435798 | ||
ICFR Auditor Attestation Flag | |||
Document Financial Statement Error Correction [Flag] | false | ||
System Energy [Member] | |||
Entity File Number | 1-09067 | ||
Entity Registrant Name | SYSTEM ENERGY RESOURCES, INC. | ||
Entity Central Index Key | 0000202584 | ||
Entity Incorporation, State or Country Code | AR | ||
Entity Address, Address Line One | 1340 Echelon Parkway | ||
Entity Address, City or Town | Jackson | ||
Entity Address, State or Province | MS | ||
Entity Address, Postal Zip Code | 39213 | ||
City Area Code | 601 | ||
Local Phone Number | 368-5000 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Interactive Data Current | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Shell Company | false | ||
Entity Emerging Growth Company | false | ||
Entity Small Business | false | ||
Entity Tax Identification Number | 72-0752777 | ||
ICFR Auditor Attestation Flag | |||
NEW YORK STOCK EXCHANGE, INC. [Member] | |||
Title of 12(b) Security | Common Stock, $0.01 Par Value | ||
Trading Symbol | ETR | ||
Security Exchange Name | NYSE | ||
NYSE CHICAGO, INC. [Member] | |||
Title of 12(b) Security | Common Stock, $0.01 Par Value | ||
Trading Symbol | ETR | ||
Security Exchange Name | CHX | ||
Mortgage Bonds 4.875% Series Due September 2066 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Arkansas [Member] | |||
Title of 12(b) Security | Mortgage Bonds, 4.875% Series due September 2066 | ||
Trading Symbol | EAI | ||
Security Exchange Name | NYSE | ||
Mortgage Bonds 4.875% Series Due September 2066 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Louisiana [Member] | |||
Title of 12(b) Security | Mortgage Bonds, 4.875% Series due September 2066 | ||
Trading Symbol | ELC | ||
Security Exchange Name | NYSE | ||
Mortgage Bonds 4.90% Series Due October 2066 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Mississippi [Member] | |||
Title of 12(b) Security | Mortgage Bonds, 4.90% Series due October 2066 | ||
Trading Symbol | EMP | ||
Security Exchange Name | NYSE | ||
Mortgage Bonds 5.0% Series Due December 2052 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy New Orleans [Member] | |||
Title of 12(b) Security | Mortgage Bonds, 5.0% Series due December 2052 | ||
Trading Symbol | ENJ | ||
Security Exchange Name | NYSE | ||
Mortgage Bonds 5.50% Series Due April 2066 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy New Orleans [Member] | |||
Title of 12(b) Security | Mortgage Bonds, 5.50% Series due April 2066 | ||
Trading Symbol | ENO | ||
Security Exchange Name | NYSE | ||
5.375% Series A Preferred Stock, Cumulative, No Par Value [Domain] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Texas [Member] | |||
Title of 12(b) Security | 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share) | ||
Trading Symbol | ETI/PR | ||
Security Exchange Name | NYSE |
Consolidated Statements Of Inco
Consolidated Statements Of Income - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 12,147,412 | $ 13,764,237 | $ 11,742,896 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 2,801,580 | 3,732,851 | 2,458,096 |
Utilities Operating Expense, Purchased Power | 968,036 | 1,561,544 | 1,271,677 |
Nuclear refueling outage expenses | 150,147 | 156,032 | 172,636 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 2,898,213 | 3,038,459 | 2,968,621 |
Asset Impairment Charges | 42,679 | (163,464) | 263,625 |
Decommissioning | 206,674 | 224,076 | 306,411 |
Taxes, Other | 755,574 | 733,538 | 660,290 |
Other Depreciation and Amortization | 1,845,003 | 1,761,023 | 1,684,286 |
Other Regulatory Charges (Credits) Net | (138,469) | 669,403 | 111,628 |
Costs and Expenses | 9,529,437 | 11,713,462 | 9,897,270 |
Operating Income (Loss) | 2,617,975 | 2,050,775 | 1,845,626 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 98,493 | 72,832 | 70,473 |
Investment Income, Net | 162,726 | (75,581) | 430,466 |
Miscellaneous - net | (201,013) | (77,629) | (201,778) |
TOTAL | 60,206 | (80,378) | 299,161 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 1,046,164 | 940,060 | 863,712 |
Allowance for borrowed funds used during construction | (39,758) | (27,823) | (29,018) |
TOTAL | 1,006,406 | 912,237 | 834,694 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 1,671,775 | 1,058,160 | 1,310,093 |
Income Tax Expense (Benefit) | (690,535) | (38,978) | 191,374 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 2,362,310 | 1,097,138 | 1,118,719 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 5,774 | (6,028) | 227 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | $ 2,356,536 | $ 1,103,166 | $ 1,118,492 |
Earnings per average common share: | |||
Earnings Per Share, Basic | $ 11.14 | $ 5.40 | $ 5.57 |
Earnings Per Share, Diluted | $ 11.10 | $ 5.37 | $ 5.54 |
Basic average number of common shares outstanding | 211,569,931 | 204,450,354 | 200,941,511 |
Diluted average number of common shares outstanding | 212,376,495 | 205,547,578 | 201,873,024 |
Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 11,842,454 | $ 13,186,845 | $ 10,873,995 |
Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 180,490 | 233,920 | 170,610 |
Other [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 124,468 | 343,472 | 698,291 |
Entergy Arkansas [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,646,396 | 2,673,194 | 2,338,590 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 514,885 | 640,344 | 347,166 |
Utilities Operating Expense, Purchased Power | 257,890 | 201,726 | 280,504 |
Nuclear refueling outage expenses | 59,973 | 53,438 | 51,141 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 737,649 | 754,293 | 687,418 |
Asset Impairment Charges | 78,434 | 0 | 0 |
Decommissioning | 87,321 | 82,326 | 77,696 |
Taxes, Other | 141,502 | 136,565 | 127,249 |
Other Depreciation and Amortization | 400,944 | 386,272 | 361,479 |
Other Regulatory Charges (Credits) Net | (87,409) | (89,418) | (31,501) |
Costs and Expenses | 2,191,189 | 2,165,546 | 1,901,152 |
Operating Income (Loss) | 455,207 | 507,648 | 437,438 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 20,587 | 17,787 | 15,273 |
Investment Income, Net | 25,024 | 19,554 | 76,953 |
Miscellaneous - net | (23,216) | (27,348) | (22,278) |
TOTAL | 22,395 | 9,993 | 69,948 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 188,232 | 150,928 | 140,348 |
Allowance for borrowed funds used during construction | (8,270) | (7,070) | (6,641) |
TOTAL | 179,962 | 143,858 | 133,707 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 297,640 | 373,783 | 373,679 |
Income Tax Expense (Benefit) | (99,210) | 80,896 | 75,195 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 396,850 | 292,887 | 298,484 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (5,231) | (4,358) | (18,092) |
Net Income (Loss) Available to Common Stockholders, Basic, Total | 402,081 | 297,245 | 316,576 |
Entergy Arkansas [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,646,396 | 2,673,194 | 2,338,590 |
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy Louisiana [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 5,147,770 | 6,338,768 | 5,068,448 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 1,080,485 | 2,002,456 | 1,302,291 |
Utilities Operating Expense, Purchased Power | 654,721 | 1,076,715 | 768,546 |
Nuclear refueling outage expenses | 63,429 | 59,698 | 49,373 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 1,097,233 | 1,139,605 | 1,034,427 |
Decommissioning | 75,962 | 72,122 | 68,575 |
Taxes, Other | 245,191 | 241,908 | 224,079 |
Other Depreciation and Amortization | 726,389 | 695,204 | 656,132 |
Other Regulatory Charges (Credits) Net | 41,209 | 148,871 | 38,245 |
Costs and Expenses | 3,984,619 | 5,436,579 | 4,141,668 |
Operating Income (Loss) | 1,163,151 | 902,189 | 926,780 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 32,160 | 26,252 | 28,648 |
Investment Income, Net | 90,316 | (69,144) | 154,606 |
Miscellaneous - net | (160,972) | 9,824 | (125,886) |
TOTAL | 264,737 | 152,758 | 184,962 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 375,295 | 373,480 | 350,227 |
Allowance for borrowed funds used during construction | (14,996) | (11,550) | (12,878) |
TOTAL | 360,299 | 361,930 | 337,349 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 1,067,589 | 693,017 | 774,393 |
Income Tax Expense (Benefit) | (205,781) | (162,853) | 120,409 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 1,273,370 | 855,870 | 653,984 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,988 | 1,366 | 0 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | 1,270,382 | 854,504 | 653,984 |
Entergy Louisiana [Member] | Affiliated Entity [Member] | |||
OTHER INCOME (DEDUCTIONS) | |||
Investment Income, Net | 303,233 | 185,826 | 127,594 |
Entergy Louisiana [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 5,073,239 | 6,246,933 | 4,994,459 |
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 74,531 | 91,835 | 73,989 |
Entergy Mississippi [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,802,533 | 1,624,234 | 1,406,346 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 563,296 | 252,760 | 181,511 |
Utilities Operating Expense, Purchased Power | 281,761 | 322,674 | 298,034 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 320,192 | 314,902 | 298,129 |
Taxes, Other | 150,921 | 137,541 | 111,712 |
Other Depreciation and Amortization | 262,624 | 246,063 | 226,545 |
Other Regulatory Charges (Credits) Net | (111,376) | 38,017 | 5,913 |
Costs and Expenses | 1,467,418 | 1,311,957 | 1,121,844 |
Operating Income (Loss) | 335,115 | 312,277 | 284,502 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 8,552 | 6,125 | 8,101 |
Investment Income, Net | 2,275 | 508 | 53 |
Miscellaneous - net | (13,231) | (3,619) | (8,791) |
TOTAL | (2,404) | 3,014 | (637) |
INTEREST EXPENSE | |||
Interest Expense, Debt | 99,857 | 86,960 | 75,124 |
Allowance for borrowed funds used during construction | (3,479) | (2,800) | (3,416) |
TOTAL | 96,378 | 84,160 | 71,708 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 236,333 | 231,131 | 212,157 |
Income Tax Expense (Benefit) | 54,364 | 54,864 | 45,323 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 181,969 | 176,267 | 166,834 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (10,302) | (21,355) | 0 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | 192,271 | 197,622 | 166,834 |
Entergy Mississippi [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,802,533 | 1,624,234 | 1,406,346 |
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy New Orleans [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 843,933 | 997,333 | 768,852 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 122,400 | 244,994 | 150,018 |
Utilities Operating Expense, Purchased Power | 268,478 | 314,283 | 268,568 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 167,719 | 156,653 | 145,377 |
Taxes, Other | 62,979 | 63,743 | 53,569 |
Other Depreciation and Amortization | 81,282 | 76,938 | 73,480 |
Other Regulatory Charges (Credits) Net | 69,211 | 19,596 | 13,177 |
Costs and Expenses | 772,069 | 876,207 | 704,189 |
Operating Income (Loss) | 71,864 | 121,126 | 64,663 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 1,470 | 829 | 2,371 |
Investment Income, Net | 7,154 | 742 | 48 |
Miscellaneous - net | (4,119) | (21) | (1,240) |
TOTAL | 4,505 | 1,550 | 1,179 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 38,118 | 34,829 | 29,164 |
Allowance for borrowed funds used during construction | (714) | (531) | (1,056) |
TOTAL | 37,404 | 34,298 | 28,108 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 38,965 | 88,378 | 37,734 |
Income Tax Expense (Benefit) | (189,973) | 24,277 | 5,936 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 228,938 | 64,101 | 31,798 |
Entergy New Orleans [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 737,974 | 855,248 | 672,231 |
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 105,959 | 142,085 | 96,621 |
Entergy Texas [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,028,586 | 2,288,905 | 1,902,511 |
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 403,111 | 443,765 | 335,742 |
Utilities Operating Expense, Purchased Power | 468,511 | 717,501 | 588,941 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 323,797 | 312,340 | 281,713 |
Taxes, Other | 117,852 | 101,673 | 94,989 |
Other Depreciation and Amortization | 278,311 | 230,692 | 214,838 |
Other Regulatory Charges (Credits) Net | 7,324 | 49,175 | 59,581 |
Costs and Expenses | 1,598,906 | 1,855,146 | 1,575,804 |
Operating Income (Loss) | 429,680 | 433,759 | 326,707 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 28,193 | 13,527 | 9,892 |
Investment Income, Net | 11,116 | 4,141 | 837 |
Miscellaneous - net | (10,411) | (6,572) | 721 |
TOTAL | 28,898 | 11,096 | 11,450 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 114,978 | 95,454 | 87,787 |
Allowance for borrowed funds used during construction | (10,545) | (4,547) | (3,980) |
TOTAL | 104,433 | 90,907 | 83,807 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 354,145 | 353,948 | 254,350 |
Income Tax Expense (Benefit) | 62,872 | 50,621 | 25,526 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 291,273 | 303,327 | 228,824 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,072 | 2,072 | 1,909 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | 289,201 | 301,255 | 226,915 |
Entergy Texas [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,028,586 | 2,288,905 | 1,902,511 |
Entergy Texas [Member] | Natural Gas, US Regulated [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
System Energy [Member] | |||
Operation and Maintenance: | |||
Utilities Operating Expense, Fuel Used | 71,762 | 50,216 | 58,313 |
Nuclear refueling outage expenses | 26,745 | 24,482 | 27,244 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 207,765 | 226,557 | 214,322 |
Decommissioning | 41,773 | 40,235 | 38,693 |
Taxes, Other | 29,224 | 29,428 | 27,842 |
Other Depreciation and Amortization | 90,858 | 111,889 | 105,978 |
Other Regulatory Charges (Credits) Net | (57,429) | 503,162 | 26,214 |
Costs and Expenses | 410,698 | 985,969 | 498,606 |
Operating Income (Loss) | 175,905 | (327,157) | 72,242 |
OTHER INCOME (DEDUCTIONS) | |||
Allowance for equity funds used during construction | 7,531 | 8,312 | 6,188 |
Investment Income, Net | 13,131 | 5,096 | 82,744 |
Miscellaneous - net | (9,101) | (19,616) | (18,991) |
TOTAL | 11,561 | (6,208) | 69,941 |
INTEREST EXPENSE | |||
Interest Expense, Debt | 48,416 | 37,381 | 38,393 |
Allowance for borrowed funds used during construction | (1,754) | (1,325) | (1,047) |
TOTAL | 46,662 | 36,056 | 37,346 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 140,804 | (369,421) | 104,837 |
Income Tax Expense (Benefit) | 32,032 | (92,828) | (1,977) |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 108,772 | (276,593) | 106,814 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | 108,772 | (276,593) | 106,814 |
System Energy [Member] | Electricity [Member] | |||
Revenues [Abstract] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 586,603 | $ 658,812 | $ 570,848 |
Consolidated Statements Of Comp
Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | $ 2,362,310 | $ 1,097,138 | $ 1,118,719 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | |||
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, after Tax | 0 | 1,035 | (29,754) |
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | 29,294 | 146,893 | 195,929 |
OCI, Debt Securities, Available-for-Sale, Gain (Loss), after Adjustment and Tax | 0 | (7,154) | (49,496) |
Other Comprehensive Income (Loss), Net of Tax, Total | 29,294 | 140,774 | 116,679 |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 2,391,604 | 1,237,912 | 1,235,398 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 5,774 | (6,028) | 227 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total | 2,385,830 | 1,243,940 | 1,235,171 |
Entergy Louisiana [Member] | |||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 1,273,370 | 855,870 | 653,984 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | |||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | (572) | 47,092 | 3,951 |
Other Comprehensive Income (Loss), Net of Tax, Total | (572) | 47,092 | 3,951 |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 1,272,798 | 902,962 | 657,935 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,988 | 1,366 | 0 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total | $ 1,269,810 | $ 901,596 | $ 657,935 |
Consolidated Statements Of Co_2
Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
OCI, Debt Securities, Available-for-Sale, Gain (Loss), after Adjustment, Tax | $ 0 | $ (2,231) | $ (28,435) |
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax | 0 | 0 | (7,935) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, before Reclassification Adjustment, Tax | 9,248 | 46,789 | 55,161 |
Entergy Louisiana [Member] | |||
Other Comprehensive (Income) Loss, Defined Benefit Plan, before Reclassification Adjustment, Tax | $ (211) | $ 17,351 | $ 1,523 |
Consolidated Statements Of Cash
Consolidated Statements Of Cash Flows - USD ($) | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | $ 2,362,310,000 | $ 1,097,138,000 | $ 1,118,719,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 2,244,479,000 | 2,190,371,000 | 2,242,944,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | (707,822,000) | (47,154,000) | 248,719,000 |
Asset Write-Offs, Impairments, And Related Charges (Credits) | 42,679,000 | (163,464,000) | 263,599,000 |
Changes in working capital: | |||
Receivables | 101,801,000 | (157,267,000) | (84,629,000) |
Fuel inventory | (45,166,000) | 6,943,000 | 18,359,000 |
Accounts payable | (135,048,000) | (102,013,000) | 269,797,000 |
Taxes accrued | 10,122,000 | 4,263,000 | (21,183,000) |
Interest accrued | 18,933,000 | 4,113,000 | (10,640,000) |
Deferred fuel costs | 759,361,000 | (393,746,000) | (466,050,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 210,038,000 | 157,235,000 | 53,883,000 |
Changes in provisions for estimated losses | (68,631,000) | 374,079,000 | (85,713,000) |
Increase (Decrease) in Other Regulatory Assets | (435,877,000) | (576,859,000) | 536,707,000 |
Increase (Decrease) in Regulatory Liabilities | 463,805,000 | (266,559,000) | 43,631,000 |
Storm restoration costs approved for securitization recognized as regulatory asset | (491,150,000) | (941,035,000) | 0 |
Changes in pension and other postretirement liabilities | (610,479,000) | (699,261,000) | (897,167,000) |
Other | (123,295,000) | (1,259,458,000) | (250,917,000) |
Net cash flow provided by operating activities | 4,294,328,000 | 2,585,490,000 | 2,300,713,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (4,440,652,000) | (5,065,126,000) | (6,087,296,000) |
Allowance for equity funds used during construction | 98,493,000 | 72,832,000 | 70,473,000 |
Litigation Proceeds from Settlement Agreement, Investing Activities | 0 | 9,829,000 | 0 |
Nuclear fuel purchases | (270,973,000) | (223,613,000) | (166,512,000) |
Payments to Acquire Productive Assets | 35,094,000 | 106,193,000 | 168,304,000 |
Net proceeds (payments) from sale of assets | 11,000,000 | (1,195,000) | 17,421,000 |
Proceeds from Insurance Settlement, Investing Activities | 19,493,000 | 0 | 0 |
Changes in securitization account | 5,493,000 | 15,514,000 | 13,669,000 |
Payments to Acquire Restricted Investments | (19,780,000) | (1,494,048,000) | (25,000) |
Receipts from storm reserve escrow accounts | 98,529,000 | 1,125,279,000 | 83,105,000 |
Decrease (increase) in other investments | (16,733,000) | (3,328,000) | 2,343,000 |
Litigation proceeds for reimbursement of spent nuclear fuel storage costs | 23,655,000 | 32,367,000 | 49,236,000 |
Proceeds from nuclear decommissioning trust fund sales | 1,082,722,000 | 1,636,686,000 | 5,553,629,000 |
Investment in nuclear decommissioning trust funds | (1,185,130,000) | (1,708,901,000) | (5,547,015,000) |
Net cash flow used in investing activities | (4,628,977,000) | (5,709,897,000) | (6,179,276,000) |
Proceeds from the issuance of: | |||
Long-term debt | 4,273,297,000 | 6,019,835,000 | 8,308,427,000 |
Proceeds from Sale of Treasury Stock | 9,823,000 | 32,042,000 | 5,977,000 |
Proceeds from Issuance of Common Stock | 130,649,000 | 852,555,000 | 200,776,000 |
Retirement of long-term debt | (5,135,753,000) | (5,995,903,000) | (4,827,827,000) |
Proceeds from securitization | 1,457,676,000 | 3,163,572,000 | 0 |
Proceeds from Noncontrolling Interests | 25,708,000 | 24,702,000 | 51,202,000 |
Changes in commercial paper - net | (310,550,000) | 373,556,000 | 426,312,000 |
Proceeds from (Payments for) Other Financing Activities | 107,595,000 | 42,761,000 | 43,221,000 |
Dividends paid: | |||
Common stock | (918,193,000) | (841,677,000) | (775,122,000) |
Preferred stock | (18,319,000) | (18,319,000) | (18,319,000) |
Net cash flow provided by financing activities | 243,033,000 | 2,906,012,000 | 2,562,023,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (91,616,000) | (218,395,000) | (1,316,540,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 132,548,000 | 224,164,000 | 442,559,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 987,252,000 | 901,884,000 | 843,228,000 |
Income taxes | 42,821,000 | 28,354,000 | 98,377,000 |
Capital Expenditures Incurred but Not yet Paid | 487,439,000 | 461,748,000 | 722,622,000 |
Entergy Arkansas [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 396,850,000 | 292,887,000 | 298,484,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 556,780,000 | 532,291,000 | 503,539,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | (102,070,000) | 78,958,000 | 100,459,000 |
Asset Write-Offs, Impairments, And Related Charges (Credits) | 78,434,000 | 0 | 0 |
Changes in working capital: | |||
Receivables | (84,428,000) | (73,579,000) | 17,682,000 |
Fuel inventory | (6,351,000) | (252,000) | (7,081,000) |
Accounts payable | (69,947,000) | 64,944,000 | 27,967,000 |
Taxes accrued | 4,625,000 | 10,936,000 | 7,753,000 |
Interest accrued | 16,554,000 | 1,708,000 | (5,637,000) |
Deferred fuel costs | 228,021,000 | (31,009,000) | (162,458,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 29,690,000 | 29,789,000 | 53,343,000 |
Changes in provisions for estimated losses | (21,039,000) | 2,914,000 | 6,915,000 |
Increase (Decrease) in Other Regulatory Assets | 6,197,000 | 120,603,000 | (142,706,000) |
Increase (Decrease) in Regulatory Liabilities | 240,762,000 | (264,054,000) | 21,066,000 |
Changes in pension and other postretirement liabilities | (109,077,000) | (67,783,000) | (175,863,000) |
Other | 152,206,000 | (302,163,000) | 172,973,000 |
Net cash flow provided by operating activities | 941,021,000 | 699,732,000 | 549,216,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (946,244,000) | (785,168,000) | (722,628,000) |
Allowance for equity funds used during construction | 20,587,000 | 17,787,000 | 15,273,000 |
Nuclear fuel purchases | (137,616,000) | (98,635,000) | (84,302,000) |
Payment for purchase of assets | 0 | (1,044,000) | (131,770,000) |
Change in money pool receivable - net | 0 | 0 | 3,110,000 |
Decrease (increase) in other investments | 1,608,000 | (1,626,000) | 0 |
Litigation proceeds for reimbursement of spent nuclear fuel storage costs | 17,933,000 | 0 | 0 |
Proceeds From Sale Leaseback Of Nuclear Fuel | 32,937,000 | 37,198,000 | 16,279,000 |
Proceeds from nuclear decommissioning trust fund sales | 117,123,000 | 248,191,000 | 530,628,000 |
Investment in nuclear decommissioning trust funds | (139,280,000) | (269,497,000) | (524,783,000) |
Net cash flow used in investing activities | (1,032,952,000) | (852,794,000) | (898,193,000) |
Proceeds from the issuance of: | |||
Long-term debt | 1,093,253,000 | 232,731,000 | 719,284,000 |
Retirement of long-term debt | (597,720,000) | (28,521,000) | (728,917,000) |
Proceeds from Noncontrolling Interests | 0 | 0 | 51,202,000 |
Change In Money Pool Payable Net | (35,410,000) | 40,891,000 | 139,904,000 |
Proceeds from (Payments for) Other Financing Activities | 47,162,000 | (13,676,000) | 38,291,000 |
Dividends paid: | |||
Common stock | (417,000,000) | (86,000,000) | (50,000,000) |
Net cash flow provided by financing activities | 90,285,000 | 145,425,000 | 169,764,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (1,646,000) | (7,637,000) | (179,213,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 3,632,000 | 5,278,000 | 12,915,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 169,173,000 | 147,060,000 | 143,561,000 |
Income taxes | 2,705,000 | (2,753,000) | (18,933,000) |
Capital Expenditures Incurred but Not yet Paid | 36,264,000 | 93,189,000 | 35,616,000 |
Entergy Louisiana [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 1,273,370,000 | 855,870,000 | 653,984,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 864,225,000 | 852,521,000 | 818,389,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | (99,812,000) | (70,379,000) | 175,700,000 |
Changes in working capital: | |||
Receivables | 55,140,000 | (53,434,000) | (58,466,000) |
Fuel inventory | (15,959,000) | 1,099,000 | 7,722,000 |
Accounts payable | (100,321,000) | (207,949,000) | 358,536,000 |
Taxes accrued | 30,459,000 | (28,244,000) | 21,631,000 |
Interest accrued | (9,680,000) | 8,284,000 | 803,000 |
Deferred fuel costs | 134,383,000 | (113,809,000) | (43,124,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 129,173,000 | 103,571,000 | 45,517,000 |
Changes in provisions for estimated losses | (52,445,000) | 291,824,000 | (449,000) |
Increase (Decrease) in Other Regulatory Assets | (407,327,000) | (720,487,000) | 1,050,600,000 |
Increase (Decrease) in Regulatory Liabilities | 225,645,000 | (4,783,000) | (16,478,000) |
Storm restoration costs approved for securitization recognized as regulatory asset | (491,150,000) | (1,190,338,000) | 0 |
Changes in pension and other postretirement liabilities | (117,886,000) | (139,067,000) | (164,263,000) |
Other | (57,997,000) | (358,997,000) | (394,658,000) |
Net cash flow provided by operating activities | 2,032,120,000 | 1,177,508,000 | 1,052,526,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (1,624,181,000) | (2,568,113,000) | (3,621,775,000) |
Allowance for equity funds used during construction | 32,160,000 | 26,252,000 | 28,648,000 |
Nuclear fuel purchases | (162,079,000) | (122,020,000) | (85,419,000) |
Net proceeds (payments) from sale of assets | 0 | 5,000,000 | 15,000,000 |
Payments for (Proceeds from) Productive Assets | 19,493,000 | 0 | 0 |
Proceeds from Insurance Settlement, Investing Activities | 0 | 5,695,000 | 0 |
Changes in securitization account | 0 | 0 | 2,700,000 |
Payments to Acquire Restricted Investments | (14,449,000) | (1,293,633,000) | 0 |
Change in money pool receivable - net | 0 | 14,539,000 | (1,113,000) |
Receipts from storm reserve escrow accounts | 64,036,000 | 1,000,228,000 | 0 |
Payments to Acquire Interest in Subsidiaries and Affiliates | (1,457,676,000) | (3,163,572,000) | 0 |
Decrease (increase) in other investments | 5,457,000 | (5,475,000) | 0 |
Litigation proceeds for reimbursement of spent nuclear fuel storage costs | 0 | 0 | 8,691,000 |
Proceeds From Sale Leaseback Of Nuclear Fuel | 30,214,000 | 37,648,000 | 13,254,000 |
Proceeds from nuclear decommissioning trust fund sales | 575,596,000 | 633,100,000 | 944,703,000 |
Investment in nuclear decommissioning trust funds | (633,029,000) | (667,947,000) | (1,004,888,000) |
Net cash flow used in investing activities | (3,039,456,000) | (4,707,711,000) | (3,700,199,000) |
Proceeds from Issuance of Trust Preferred Securities | 125,002,000 | 1,390,587,000 | 0 |
Proceeds from the issuance of: | |||
Long-term debt | 1,410,893,000 | 2,942,771,000 | 3,769,166,000 |
Retirement of long-term debt | (2,699,235,000) | (3,167,832,000) | (1,895,091,000) |
Proceeds from Contributions from Parent | 1,457,676,000 | 1,000,000,000 | 125,000,000 |
Proceeds from securitization | 1,457,676,000 | 3,163,572,000 | 0 |
Change In Money Pool Payable Net | (69,948,000) | 226,114,000 | 0 |
Proceeds from (Payments for) Other Financing Activities | 57,183,000 | 27,618,000 | (849,000) |
Dividends paid: | |||
Common stock | (660,750,000) | (624,000,000) | (60,000,000) |
Net cash flow provided by financing activities | 953,495,000 | 3,568,243,000 | 1,938,226,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (53,841,000) | 38,040,000 | (709,447,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 2,772,000 | 56,613,000 | 18,573,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 376,353,000 | 353,697,000 | 337,926,000 |
Income taxes | (141,143,000) | (82,463,000) | (18,453,000) |
Capital Expenditures Incurred but Not yet Paid | 105,859,000 | 156,654,000 | 507,855,000 |
Entergy Mississippi [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 181,969,000 | 176,267,000 | 166,834,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 262,624,000 | 246,063,000 | 226,545,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 28,990,000 | 54,850,000 | 64,868,000 |
Changes in working capital: | |||
Receivables | 3,627,000 | (65,843,000) | 10,260,000 |
Fuel inventory | (648,000) | (5,237,000) | 6,806,000 |
Accounts payable | (41,101,000) | 49,101,000 | 27,068,000 |
Taxes accrued | (9,771,000) | 18,632,000 | (1,811,000) |
Interest accrued | 3,329,000 | 925,000 | (3,606,000) |
Deferred fuel costs | 273,856,000 | (21,333,000) | (136,569,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 23,813,000 | (2,632,000) | 9,522,000 |
Changes in provisions for estimated losses | 1,972,000 | (519,000) | (8,476,000) |
Increase (Decrease) in Other Regulatory Assets | 59,616,000 | 57,028,000 | (4,909,000) |
Increase (Decrease) in Regulatory Liabilities | (59,513,000) | 20,165,000 | 21,930,000 |
Changes in pension and other postretirement liabilities | (49,223,000) | (35,299,000) | (51,828,000) |
Other | (46,709,000) | (22,273,000) | (33,552,000) |
Net cash flow provided by operating activities | 559,391,000 | 405,649,000 | 350,960,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (562,118,000) | (534,020,000) | (654,352,000) |
Allowance for equity funds used during construction | 8,552,000 | 6,125,000 | 8,101,000 |
Payment for purchase of assets | (35,094,000) | (105,149,000) | 0 |
Change in money pool receivable - net | 26,879,000 | 13,577,000 | (40,456,000) |
Receipts from storm reserve escrow accounts | 34,493,000 | 0 | 0 |
Decrease (increase) in other investments | (690,000) | (1,273,000) | 53,000 |
Net cash flow used in investing activities | (527,978,000) | (620,740,000) | (686,654,000) |
Proceeds from the issuance of: | |||
Long-term debt | 396,833,000 | 249,266,000 | 398,284,000 |
Retirement of long-term debt | (500,000,000) | (100,000,000) | 0 |
Proceeds from Noncontrolling Interests | 25,708,000 | 24,702,000 | 0 |
Change In Money Pool Payable Net | 73,769,000 | 0 | (16,516,000) |
Proceeds from (Payments for) Other Financing Activities | 1,928,000 | 10,475,000 | 1,535,000 |
Dividends paid: | |||
Common stock | (40,000,000) | 0 | 0 |
Net cash flow provided by financing activities | (41,762,000) | 184,443,000 | 383,303,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (10,349,000) | (30,648,000) | 47,609,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 6,630,000 | 16,979,000 | 47,627,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 93,961,000 | 83,291,000 | 76,245,000 |
Income taxes | 50,869,000 | (5,396,000) | (19,672,000) |
Capital Expenditures Incurred but Not yet Paid | 16,342,000 | 59,474,000 | 26,498,000 |
Entergy New Orleans [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 228,938,000 | 64,101,000 | 31,798,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 81,282,000 | 76,938,000 | 73,480,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | (191,326,000) | 18,685,000 | 12,573,000 |
Changes in working capital: | |||
Receivables | 29,944,000 | 6,128,000 | (42,612,000) |
Fuel inventory | 2,574,000 | (2,927,000) | (967,000) |
Accounts payable | (11,924,000) | 21,000 | 22,457,000 |
Taxes accrued | (11,882,000) | 5,923,000 | (315,000) |
Interest accrued | 454,000 | 89,000 | (104,000) |
Deferred fuel costs | 4,005,000 | (17,760,000) | 9,737,000 |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 9,184,000 | 790,000 | 3,233,000 |
Changes in provisions for estimated losses | 1,076,000 | 80,719,000 | (83,569,000) |
Increase (Decrease) in Other Regulatory Assets | (19,745,000) | (46,505,000) | (18,173,000) |
Increase (Decrease) in Regulatory Liabilities | 66,022,000 | (8,639,000) | 4,985,000 |
Storm restoration costs approved for securitization recognized as regulatory asset | 0 | 95,920,000 | 0 |
Changes in pension and other postretirement liabilities | (16,371,000) | 9,769,000 | (32,144,000) |
Other | (9,603,000) | 10,919,000 | (68,549,000) |
Net cash flow provided by operating activities | 202,956,000 | 363,763,000 | 78,808,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (164,279,000) | (217,864,000) | (220,284,000) |
Allowance for equity funds used during construction | 1,470,000 | 829,000 | 2,371,000 |
Changes in securitization account | (191,000) | (236,000) | 1,365,000 |
Payments to Acquire Restricted Investments | (3,731,000) | (200,000,000) | (7,000) |
Change in money pool receivable - net | 147,254,000 | (110,844,000) | (36,410,000) |
Receipts from storm reserve escrow accounts | 0 | 125,000,000 | 83,045,000 |
Decrease (increase) in other investments | 675,000 | (675,000) | 0 |
Net cash flow used in investing activities | (18,802,000) | (403,790,000) | (169,920,000) |
Proceeds from the issuance of: | |||
Long-term debt | 14,610,000 | 0 | 183,403,000 |
Retirement of long-term debt | (112,525,000) | (12,207,000) | (36,873,000) |
Proceeds from Contribution in Aid of Construction | 15,000,000 | 15,000,000 | 0 |
Change In Money Pool Payable Net | 21,651,000 | 0 | (10,190,000) |
Repayment of long-term payable due to Entergy Louisiana | (1,306,000) | (1,326,000) | (1,618,000) |
Proceeds from (Payments for) Other Financing Activities | (1,022,000) | 162,000 | (774,000) |
Dividends paid: | |||
Common stock | (125,000,000) | 0 | 0 |
Net cash flow provided by financing activities | (188,592,000) | 1,629,000 | 133,948,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (4,438,000) | (38,398,000) | 42,836,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 26,000 | 4,464,000 | 42,862,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 36,263,000 | 33,343,000 | 28,009,000 |
Income taxes | 14,120,000 | 499,000 | (3,839,000) |
Capital Expenditures Incurred but Not yet Paid | 7,068,000 | 11,152,000 | 0 |
Entergy Texas [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 291,273,000 | 303,327,000 | 228,824,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 278,311,000 | 230,692,000 | 214,838,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 53,507,000 | 41,648,000 | 48,813,000 |
Changes in working capital: | |||
Receivables | 24,249,000 | (35,131,000) | (16,455,000) |
Fuel inventory | (24,097,000) | 15,962,000 | 10,819,000 |
Accounts payable | (22,046,000) | 48,199,000 | (5,718,000) |
Taxes accrued | (14,146,000) | 44,015,000 | (3,420,000) |
Interest accrued | 7,357,000 | 4,926,000 | (1,854,000) |
Deferred fuel costs | 119,096,000 | (209,835,000) | (133,636,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | 36,097,000 | 19,574,000 | 12,105,000 |
Changes in provisions for estimated losses | 1,887,000 | (649,000) | (140,000) |
Increase (Decrease) in Other Regulatory Assets | 17,924,000 | 157,349,000 | (103,380,000) |
Increase (Decrease) in Regulatory Liabilities | (20,122,000) | (30,499,000) | (28,747,000) |
Storm restoration costs approved for securitization recognized as regulatory asset | 0 | 153,383,000 | 0 |
Changes in pension and other postretirement liabilities | (36,131,000) | 20,656,000 | (42,502,000) |
Other | (36,574,000) | 344,000 | 5,164,000 |
Net cash flow provided by operating activities | 641,691,000 | 409,427,000 | 356,933,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (946,543,000) | (696,879,000) | (702,754,000) |
Allowance for equity funds used during construction | 28,193,000 | 13,527,000 | 9,892,000 |
Litigation Proceeds from Settlement Agreement, Investing Activities | 0 | 4,134,000 | 0 |
Payments to Acquire Productive Assets | 0 | 0 | 36,534,000 |
Net proceeds (payments) from sale of assets | 11,000,000 | 0 | 67,920,000 |
Changes in securitization account | 5,684,000 | 15,750,000 | 9,604,000 |
Change in money pool receivable - net | (218,414,000) | (99,468,000) | 4,601,000 |
Decrease (increase) in other investments | (5,868,000) | (1,133,000) | 0 |
Net cash flow used in investing activities | (1,125,948,000) | (764,069,000) | (647,271,000) |
Proceeds from the issuance of: | |||
Long-term debt | 344,895,000 | 606,168,000 | 127,931,000 |
Proceeds from Issuance of Preferred Stock and Preference Stock | 0 | 0 | 3,713,000 |
Retirement of long-term debt | (17,835,000) | (66,514,000) | (269,435,000) |
Proceeds from Contributions from Parent | 150,000,000 | 0 | 95,000,000 |
Change In Money Pool Payable Net | 0 | (79,594,000) | 79,594,000 |
Proceeds from (Payments for) Other Financing Activities | 27,758,000 | 5,111,000 | 6,848,000 |
Dividends paid: | |||
Common stock | 0 | (105,000,000) | 0 |
Preferred stock | (2,072,000) | (2,060,000) | (1,881,000) |
Net cash flow provided by financing activities | 502,746,000 | 358,111,000 | 41,770,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 18,489,000 | 3,469,000 | (248,568,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 21,986,000 | 3,497,000 | 28,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 104,766,000 | 87,682,000 | 87,094,000 |
Income taxes | 28,969,000 | 1,864,000 | 17,594,000 |
Capital Expenditures Incurred but Not yet Paid | 257,467,000 | 68,893,000 | 73,105,000 |
System Energy [Member] | |||
Net Cash Provided by (Used in) Operating Activities [Abstract] | |||
Consolidated net income | 108,772,000 | (276,593,000) | 106,814,000 |
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract] | |||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 195,045,000 | 194,411,000 | 198,067,000 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 32,982,000 | (85,720,000) | 11,191,000 |
Changes in working capital: | |||
Receivables | 8,359,000 | (19,530,000) | 6,054,000 |
Accounts payable | 78,655,000 | (11,948,000) | 23,973,000 |
Taxes accrued | 19,804,000 | (25,321,000) | (50,059,000) |
Interest accrued | 1,363,000 | (123,000) | (1,008,000) |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | (20,749,000) | 38,764,000 | (25,096,000) |
Increase (Decrease) in Other Regulatory Assets | 31,239,000 | 19,575,000 | (143,417,000) |
Increase (Decrease) in Regulatory Liabilities | 11,009,000 | 21,252,000 | 40,884,000 |
Changes in pension and other postretirement liabilities | (21,259,000) | (35,354,000) | (49,308,000) |
Other | 150,668,000 | (304,545,000) | 253,910,000 |
Net cash flow provided by operating activities | 273,572,000 | 7,280,000 | 201,211,000 |
INVESTING ACTIVITIES | |||
Construction/capital expenditures | (121,075,000) | (164,797,000) | (100,474,000) |
Allowance for equity funds used during construction | 7,531,000 | 8,312,000 | 6,188,000 |
Nuclear fuel purchases | (80,663,000) | (96,659,000) | (45,180,000) |
Change in money pool receivable - net | 94,981,000 | (19,236,000) | (71,741,000) |
Decrease (increase) in other investments | (3,000) | 300,000 | (300,000) |
Proceeds From Sale Leaseback Of Nuclear Fuel | 46,242,000 | 18,855,000 | 21,724,000 |
Proceeds from nuclear decommissioning trust fund sales | 390,004,000 | 346,504,000 | 1,022,170,000 |
Investment in nuclear decommissioning trust funds | (412,823,000) | (357,463,000) | (1,025,779,000) |
Net cash flow used in investing activities | (75,806,000) | (264,184,000) | (193,392,000) |
Proceeds from the issuance of: | |||
Long-term debt | 715,545,000 | 1,022,472,000 | 662,423,000 |
Retirement of long-term debt | (758,437,000) | (986,829,000) | (727,510,000) |
Proceeds from Contributions from Parent | 0 | 135,000,000 | 0 |
Change In Money Pool Payable Net | 12,246,000 | 0 | 0 |
Dividends paid: | |||
Common stock | (170,000,000) | 0 | (96,000,000) |
Net cash flow provided by financing activities | (200,646,000) | 170,643,000 | (161,087,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (2,880,000) | (86,261,000) | (153,268,000) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 60,000 | 2,940,000 | 89,201,000 |
Cash paid during the period for: | |||
Interest - net of amount capitalized | 45,196,000 | 39,848,000 | 39,340,000 |
Income taxes | (19,810,000) | 18,413,000 | 54,959,000 |
Capital Expenditures Incurred but Not yet Paid | $ 25,301,000 | $ 28,960,000 | $ 23,388,000 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) | Dec. 31, 2023 | Dec. 31, 2022 |
Cash and cash equivalents: | ||
Cash | $ 71,609,000 | $ 115,290,000 |
Temporary cash investments | 60,939,000 | 108,874,000 |
Total cash and cash equivalents | 132,548,000 | 224,164,000 |
Restricted Cash and Cash Equivalents, Current | 8,000,000 | 13,000,000 |
Accounts receivable: | ||
Customer | 699,411,000 | 788,552,000 |
Allowance for doubtful accounts | (25,905,000) | (30,856,000) |
Other | 225,334,000 | 241,702,000 |
Accrued unbilled revenues | 494,615,000 | 495,859,000 |
Total accounts receivable | 1,393,455,000 | 1,495,257,000 |
Deferred fuel costs | 169,967,000 | 710,401,000 |
Fuel inventory - at average cost | 192,799,000 | 147,632,000 |
Public Utilities, Inventory | 1,418,969,000 | 1,183,308,000 |
Deferred nuclear refueling outage costs | 140,115,000 | 143,653,000 |
Prepayments and other | 213,016,000 | 190,611,000 |
TOTAL | 3,660,869,000 | 4,095,026,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 4,863,710,000 | 4,121,864,000 |
Storm Reserve Escrow Account | 323,206,000 | 401,955,000 |
Non-utility property - at cost (less accumulated depreciation) | 418,546,000 | 366,405,000 |
Other | 69,494,000 | 102,259,000 |
TOTAL | 5,674,956,000 | 4,992,483,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 66,850,474,000 | 64,646,911,000 |
Natural gas | 717,503,000 | 691,970,000 |
Construction work in progress | 2,109,703,000 | 1,844,171,000 |
Nuclear fuel | 707,852,000 | 582,119,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 70,385,532,000 | 67,765,171,000 |
Less - accumulated depreciation and amortization | 26,551,203,000 | 25,288,047,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 43,834,329,000 | 42,477,124,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 5,669,404,000 | 6,036,397,000 |
Deferred Fuel Cost Non Current | 172,201,000 | 241,085,000 |
Goodwill | 374,099,000 | 377,172,000 |
Deferred Income Tax Assets, Net | 16,367,000 | 84,100,000 |
Other | 301,171,000 | 291,804,000 |
Deferred Costs and Other Assets | 6,533,242,000 | 7,030,558,000 |
TOTAL ASSETS | 59,703,396,000 | 58,595,191,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 2,099,057,000 | 2,309,037,000 |
Short-Term Debt | 1,138,171,000 | 827,621,000 |
Accounts payable | 1,566,745,000 | 1,777,590,000 |
Customer deposits | 446,146,000 | 424,723,000 |
Taxes accrued | 434,213,000 | 424,091,000 |
Interest accrued | 214,197,000 | 195,264,000 |
Deferred fuel costs | 218,927,000 | 0 |
Pension and other postretirement liabilities | 59,508,000 | 104,845,000 |
Sale-leaseback/depreciation regulatory liability | 0 | 103,497,000 |
Other | 219,528,000 | 202,779,000 |
TOTAL | 6,396,492,000 | 6,369,447,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 4,245,982,000 | 4,818,837,000 |
Accumulated deferred investment tax credits | 205,973,000 | 211,220,000 |
Regulatory Liability For Income Taxes Net | 1,033,242,000 | 1,258,276,000 |
Other regulatory liabilities | 3,116,926,000 | 2,324,590,000 |
Asset Retirement Obligations, Noncurrent | 4,505,782,000 | 4,271,531,000 |
Loss Contingency Accrual | 462,570,000 | 531,201,000 |
Pension and other postretirement liabilities | 648,413,000 | 1,213,555,000 |
Long-Term Debt, Excluding Current Maturities | 23,008,839,000 | 23,623,512,000 |
Deferred Credits and Other Liabilities | 1,116,661,000 | 688,720,000 |
TOTAL | 38,344,388,000 | 38,941,442,000 |
Commitments and Contingencies | ||
Subsidiaries’ preferred stock without sinking fund | $ 219,410,000 | $ 219,410,000 |
Preferred Stock, Shares Issued | 0 | 0 |
Preferred Stock, Shares Authorized | 1,000,000 | 1,000,000 |
EQUITY | ||
Common Stock, Value, Issued | $ 2,810,000 | $ 2,797,000 |
Additional Paid in Capital, Common Stock | 7,795,411,000 | 7,632,895,000 |
Retained Earnings (Accumulated Deficit) | 11,940,384,000 | 10,502,041,000 |
Accumulated other comprehensive loss | (162,460,000) | (191,754,000) |
Treasury Stock, Value | 4,953,498,000 | 4,978,994,000 |
Total shareholders' equity | 14,622,647,000 | 12,966,985,000 |
Total shareholders' equity | 14,743,106,000 | 13,064,892,000 |
Equity, Attributable to Noncontrolling Interest | 120,459,000 | 97,907,000 |
TOTAL LIABILITIES AND EQUITY | 59,703,396,000 | 58,595,191,000 |
Preferred Stock, Value, Issued | $ 0 | $ 0 |
Preferred Stock, Shares Issued | $ 0 | $ 0 |
Common Stock, Shares, Issued | 280,975,348 | 279,653,929 |
Common Stock, Shares Authorized | 499,000,000 | 499,000,000 |
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 |
Entergy New Orleans [Member] | ||
Cash and cash equivalents: | ||
Cash | $ 26,000 | $ 27,000 |
Temporary cash investments | 0 | 4,437,000 |
Total cash and cash equivalents | 26,000 | 4,464,000 |
Restricted Cash and Cash Equivalents, Current | 2,426,000 | 2,235,000 |
Accounts receivable: | ||
Customer | 67,258,000 | 93,288,000 |
Allowance for doubtful accounts | (7,770,000) | (11,909,000) |
Other | 5,270,000 | 6,110,000 |
Accrued unbilled revenues | 31,087,000 | 37,284,000 |
Total accounts receivable | 97,502,000 | 274,700,000 |
Deferred fuel costs | 6,148,000 | 10,153,000 |
Fuel inventory - at average cost | 3,298,000 | 5,872,000 |
Public Utilities, Inventory | 30,019,000 | 22,498,000 |
Prepaid Taxes | 1,574,000 | 0 |
Prepayments and other | 11,482,000 | 6,312,000 |
TOTAL | 152,475,000 | 326,234,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Storm Reserve Escrow Account | 78,731,000 | 75,000,000 |
Non-utility property - at cost (less accumulated depreciation) | 832,000 | 1,050,000 |
Other | 0 | 675,000 |
TOTAL | 79,563,000 | 76,725,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 2,046,928,000 | 1,934,837,000 |
Natural gas | 401,846,000 | 390,252,000 |
Construction work in progress | 25,424,000 | 39,607,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 2,474,198,000 | 2,364,696,000 |
Less - accumulated depreciation and amortization | 858,672,000 | 808,224,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 1,615,526,000 | 1,556,472,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 182,367,000 | 202,112,000 |
Deferred Fuel Cost Non Current | 4,080,000 | 4,080,000 |
Other | 63,964,000 | 46,778,000 |
Deferred Costs and Other Assets | 250,411,000 | 252,970,000 |
TOTAL ASSETS | 2,097,975,000 | 2,212,401,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 85,000,000 | 170,000,000 |
Accounts Payable | 76,736,000 | 53,258,000 |
Notes Payable, Current | 1,275,000 | 1,306,000 |
Accounts payable | 39,813,000 | 57,291,000 |
Customer deposits | 32,420,000 | 31,826,000 |
Taxes accrued | 0 | 10,308,000 |
Interest accrued | 8,534,000 | 8,080,000 |
Other | 8,953,000 | 6,560,000 |
TOTAL | 252,731,000 | 338,629,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 195,615,000 | 385,259,000 |
Accumulated deferred investment tax credits | 16,457,000 | 16,481,000 |
Regulatory Liability For Income Taxes Net | 36,061,000 | 39,738,000 |
Other regulatory liabilities | 90,434,000 | 20,735,000 |
Loss Contingency Accrual | 88,124,000 | 87,048,000 |
Long-Term Debt, Excluding Current Maturities | 584,171,000 | 596,047,000 |
Notes Payable, Noncurrent | 7,004,000 | 8,279,000 |
Deferred Credits and Other Liabilities | 20,624,000 | 17,369,000 |
TOTAL | 1,038,490,000 | 1,170,956,000 |
Commitments and Contingencies | ||
Members' Equity | 806,754,000 | 702,816,000 |
EQUITY | ||
Total shareholders' equity | 806,754,000 | 702,816,000 |
Members' Equity | 806,754,000 | 702,816,000 |
TOTAL LIABILITIES AND EQUITY | 2,097,975,000 | 2,212,401,000 |
Entergy New Orleans [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 1,657,000 | 149,927,000 |
Entergy Louisiana [Member] | ||
Cash and cash equivalents: | ||
Cash | 2,255,000 | 50,318,000 |
Temporary cash investments | 517,000 | 6,295,000 |
Total cash and cash equivalents | 2,772,000 | 56,613,000 |
Accounts receivable: | ||
Customer | 264,776,000 | 339,291,000 |
Allowance for doubtful accounts | (6,156,000) | (7,595,000) |
Other | 74,685,000 | 53,241,000 |
Accrued unbilled revenues | 202,173,000 | 199,077,000 |
Total accounts receivable | 617,770,000 | 672,910,000 |
Deferred fuel costs | 24,800,000 | 159,183,000 |
Fuel inventory - at average cost | 57,818,000 | 41,859,000 |
Public Utilities, Inventory | 652,180,000 | 555,860,000 |
Deferred nuclear refueling outage costs | 96,047,000 | 53,833,000 |
Prepayments and other | 71,613,000 | 76,646,000 |
TOTAL | 1,523,000,000 | 1,616,904,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 2,107,384,000 | 1,779,090,000 |
Storm Reserve Escrow Account | 243,819,000 | 293,406,000 |
Non-utility property - at cost (less accumulated depreciation) | 404,043,000 | 350,723,000 |
Other | 9,367,000 | 19,679,000 |
TOTAL | 7,260,858,000 | 5,606,470,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 27,800,467,000 | 27,498,136,000 |
Natural gas | 315,658,000 | 301,719,000 |
Construction work in progress | 592,803,000 | 736,969,000 |
Nuclear fuel | 333,472,000 | 212,941,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 29,042,400,000 | 28,749,765,000 |
Less - accumulated depreciation and amortization | 10,570,707,000 | 10,087,942,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 18,471,693,000 | 18,661,823,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 1,648,852,000 | 2,056,179,000 |
Deferred Fuel Cost Non Current | 168,122,000 | 168,122,000 |
Other | 36,945,000 | 35,057,000 |
Deferred Costs and Other Assets | 1,853,919,000 | 2,259,358,000 |
TOTAL ASSETS | 29,109,470,000 | 28,144,555,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 1,400,000,000 | 1,010,000,000 |
Accounts Payable | 283,016,000 | 356,688,000 |
Accounts payable | 467,414,000 | 589,355,000 |
Customer deposits | 167,905,000 | 161,666,000 |
Taxes accrued | 66,463,000 | 36,004,000 |
Interest accrued | 91,656,000 | 101,336,000 |
Other | 87,468,000 | 72,525,000 |
TOTAL | 2,563,922,000 | 2,327,574,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 2,391,442,000 | 2,374,878,000 |
Accumulated deferred investment tax credits | 93,242,000 | 97,868,000 |
Regulatory Liability For Income Taxes Net | 193,754,000 | 337,836,000 |
Other regulatory liabilities | 1,407,689,000 | 1,037,962,000 |
Asset Retirement Obligations, Noncurrent | 1,836,240,000 | 1,736,801,000 |
Loss Contingency Accrual | 263,869,000 | 316,314,000 |
Pension and other postretirement liabilities | 271,928,000 | 389,631,000 |
Long-Term Debt, Excluding Current Maturities | 8,020,689,000 | 9,688,922,000 |
Deferred Credits and Other Liabilities | 493,176,000 | 343,321,000 |
TOTAL | 14,972,029,000 | 16,323,533,000 |
Commitments and Contingencies | ||
Members' Equity | 11,473,614,000 | 9,406,343,000 |
Members' Equity Attributable to Noncontrolling Interest | $ 45,107,000 | $ 31,735,000 |
Preferred Stock, Shares Authorized | 0 | 0 |
EQUITY | ||
Accumulated other comprehensive loss | $ 54,798,000 | $ 55,370,000 |
Total shareholders' equity | 11,573,519,000 | 9,493,448,000 |
Members' Equity | 11,473,614,000 | 9,406,343,000 |
TOTAL LIABILITIES AND EQUITY | 29,109,470,000 | 28,144,555,000 |
Entergy Louisiana [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 82,292,000 | 88,896,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Investment Owned, Fair Value | 4,496,245,000 | 3,163,572,000 |
Entergy Arkansas [Member] | ||
Cash and cash equivalents: | ||
Cash | 520,000 | 1,911,000 |
Temporary cash investments | 3,112,000 | 3,367,000 |
Total cash and cash equivalents | 3,632,000 | 5,278,000 |
Accounts receivable: | ||
Customer | 157,520,000 | 140,513,000 |
Allowance for doubtful accounts | (7,182,000) | (6,528,000) |
Other | 89,532,000 | 101,096,000 |
Accrued unbilled revenues | 117,119,000 | 116,816,000 |
Total accounts receivable | 481,661,000 | 397,233,000 |
Deferred fuel costs | 0 | 139,739,000 |
Fuel inventory - at average cost | 57,495,000 | 51,144,000 |
Public Utilities, Inventory | 358,302,000 | 288,260,000 |
Deferred nuclear refueling outage costs | 35,463,000 | 56,443,000 |
Prepayments and other | 40,866,000 | 26,576,000 |
TOTAL | 977,419,000 | 964,673,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 1,414,009,000 | 1,199,860,000 |
Other | 801,000 | 2,414,000 |
TOTAL | 1,414,810,000 | 1,202,274,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 14,821,814,000 | 14,077,844,000 |
Construction work in progress | 340,601,000 | 417,244,000 |
Nuclear fuel | 213,722,000 | 176,174,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 15,376,137,000 | 14,671,262,000 |
Less - accumulated depreciation and amortization | 6,002,203,000 | 5,729,304,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 9,373,934,000 | 8,941,958,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 1,885,361,000 | 1,810,281,000 |
Deferred Fuel Cost Non Current | 0 | 68,883,000 |
Other | 21,334,000 | 18,507,000 |
Deferred Costs and Other Assets | 1,906,695,000 | 1,897,671,000 |
TOTAL ASSETS | 13,672,858,000 | 13,006,576,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 375,000,000 | 290,000,000 |
Accounts Payable | 225,344,000 | 276,362,000 |
Accounts payable | 215,502,000 | 310,339,000 |
Customer deposits | 113,186,000 | 102,799,000 |
Taxes accrued | 105,151,000 | 100,526,000 |
Interest accrued | 35,370,000 | 18,816,000 |
Deferred fuel costs | 88,282,000 | 0 |
Other | 55,683,000 | 43,394,000 |
TOTAL | 1,213,518,000 | 1,142,236,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 1,437,053,000 | 1,498,234,000 |
Accumulated deferred investment tax credits | 27,270,000 | 28,472,000 |
Regulatory Liability For Income Taxes Net | 392,496,000 | 435,157,000 |
Other regulatory liabilities | 759,181,000 | 475,758,000 |
Asset Retirement Obligations, Noncurrent | 1,560,057,000 | 1,472,736,000 |
Loss Contingency Accrual | 58,959,000 | 79,998,000 |
Pension and other postretirement liabilities | 8,901,000 | 118,020,000 |
Long-Term Debt, Excluding Current Maturities | 4,298,080,000 | 3,876,500,000 |
Deferred Credits and Other Liabilities | 156,673,000 | 97,650,000 |
TOTAL | 8,698,670,000 | 8,082,525,000 |
Commitments and Contingencies | ||
Members' Equity | 3,739,071,000 | 3,753,990,000 |
Members' Equity Attributable to Noncontrolling Interest | $ 21,599,000 | $ 27,825,000 |
Preferred Stock, Shares Authorized | 0 | 0 |
EQUITY | ||
Total shareholders' equity | $ 3,760,670,000 | $ 3,781,815,000 |
Members' Equity | 3,739,071,000 | 3,753,990,000 |
TOTAL LIABILITIES AND EQUITY | 13,672,858,000 | 13,006,576,000 |
Entergy Arkansas [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 124,672,000 | 45,336,000 |
Entergy Mississippi [Member] | ||
Cash and cash equivalents: | ||
Cash | 30,000 | 26,000 |
Temporary cash investments | 6,600,000 | 16,953,000 |
Total cash and cash equivalents | 6,630,000 | 16,979,000 |
Accounts receivable: | ||
Customer | 121,389,000 | 99,504,000 |
Allowance for doubtful accounts | (3,312,000) | (2,472,000) |
Other | 17,697,000 | 34,564,000 |
Accrued unbilled revenues | 71,465,000 | 73,473,000 |
Total accounts receivable | 212,236,000 | 242,742,000 |
Deferred fuel costs | 0 | 143,211,000 |
Fuel inventory - at average cost | 16,196,000 | 15,548,000 |
Public Utilities, Inventory | 95,526,000 | 84,346,000 |
Prepayments and other | 12,740,000 | 9,603,000 |
TOTAL | 343,328,000 | 512,429,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Storm Reserve Escrow Account | 656,000 | 33,549,000 |
Non-utility property - at cost (less accumulated depreciation) | 4,497,000 | 4,512,000 |
Other | 0 | 910,000 |
TOTAL | 5,153,000 | 38,971,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 7,455,145,000 | 7,079,849,000 |
Construction work in progress | 139,635,000 | 170,191,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 7,594,780,000 | 7,250,040,000 |
Less - accumulated depreciation and amortization | 2,346,327,000 | 2,264,786,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 5,248,453,000 | 4,985,254,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 579,076,000 | 519,460,000 |
Other | 51,996,000 | 22,650,000 |
Deferred Costs and Other Assets | 631,072,000 | 542,110,000 |
TOTAL ASSETS | 6,228,006,000 | 6,078,764,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 100,000,000 | 400,000,000 |
Accounts Payable | 133,571,000 | 60,532,000 |
Accounts payable | 92,659,000 | 176,162,000 |
Customer deposits | 92,637,000 | 89,668,000 |
Taxes accrued | 115,134,000 | 124,905,000 |
Interest accrued | 21,537,000 | 18,208,000 |
Deferred fuel costs | 130,645,000 | 0 |
Other | 26,463,000 | 38,908,000 |
TOTAL | 712,646,000 | 908,383,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 821,744,000 | 780,030,000 |
Accumulated deferred investment tax credits | 13,811,000 | 14,591,000 |
Regulatory Liability For Income Taxes Net | 188,714,000 | 202,058,000 |
Other regulatory liabilities | 33,696,000 | 79,865,000 |
Asset Retirement Obligations, Noncurrent | 8,229,000 | 7,797,000 |
Loss Contingency Accrual | 39,481,000 | 37,509,000 |
Pension and other postretirement liabilities | 0 | 23,742,000 |
Long-Term Debt, Excluding Current Maturities | 2,129,510,000 | 1,931,096,000 |
Deferred Credits and Other Liabilities | 71,961,000 | 53,156,000 |
TOTAL | 3,307,146,000 | 3,129,844,000 |
Commitments and Contingencies | ||
Members' Equity | 2,189,461,000 | 2,037,190,000 |
Members' Equity Attributable to Noncontrolling Interest | $ 18,753,000 | $ 3,347,000 |
Preferred Stock, Shares Authorized | 0 | 0 |
EQUITY | ||
Total shareholders' equity | $ 2,208,214,000 | $ 2,040,537,000 |
Members' Equity | 2,189,461,000 | 2,037,190,000 |
TOTAL LIABILITIES AND EQUITY | 6,228,006,000 | 6,078,764,000 |
Entergy Mississippi [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 4,997,000 | 37,673,000 |
Entergy Texas [Member] | ||
Cash and cash equivalents: | ||
Cash | 1,497,000 | 500,000 |
Temporary cash investments | 20,489,000 | 2,997,000 |
Total cash and cash equivalents | 21,986,000 | 3,497,000 |
Restricted Cash and Cash Equivalents, Current | 5,195,000 | 10,879,000 |
Accounts receivable: | ||
Customer | 88,468,000 | 115,955,000 |
Allowance for doubtful accounts | (1,484,000) | (2,352,000) |
Other | 24,416,000 | 21,587,000 |
Accrued unbilled revenues | 72,771,000 | 69,208,000 |
Total accounts receivable | 514,112,000 | 319,947,000 |
Deferred fuel costs | 139,019,000 | 258,115,000 |
Fuel inventory - at average cost | 50,847,000 | 26,750,000 |
Public Utilities, Inventory | 123,020,000 | 93,031,000 |
Prepayments and other | 35,232,000 | 20,568,000 |
TOTAL | 889,411,000 | 732,787,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Non-utility property - at cost (less accumulated depreciation) | 376,000 | 376,000 |
Other | 15,068,000 | 18,975,000 |
TOTAL | 15,658,000 | 19,601,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 7,931,340,000 | 7,409,461,000 |
Construction work in progress | 857,707,000 | 339,139,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 8,789,047,000 | 7,748,600,000 |
Less - accumulated depreciation and amortization | 2,363,919,000 | 2,135,400,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 6,425,128,000 | 5,613,200,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 596,606,000 | 578,682,000 |
Other | 129,769,000 | 99,694,000 |
Deferred Costs and Other Assets | 726,375,000 | 678,376,000 |
TOTAL ASSETS | 8,056,572,000 | 7,043,964,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 0 | 0 |
Accounts Payable | 74,423,000 | 70,321,000 |
Accounts payable | 195,703,000 | 201,982,000 |
Customer deposits | 39,999,000 | 38,764,000 |
Taxes accrued | 78,887,000 | 93,033,000 |
Interest accrued | 31,285,000 | 23,928,000 |
Other | 16,237,000 | 16,963,000 |
TOTAL | 436,534,000 | 444,991,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 814,905,000 | 744,227,000 |
Accumulated deferred investment tax credits | 7,963,000 | 8,711,000 |
Regulatory Liability For Income Taxes Net | 114,759,000 | 132,647,000 |
Other regulatory liabilities | 43,013,000 | 45,247,000 |
Asset Retirement Obligations, Noncurrent | 11,743,000 | 11,121,000 |
Loss Contingency Accrual | 9,480,000 | 7,593,000 |
Long-Term Debt, Excluding Current Maturities | 3,225,092,000 | 2,895,913,000 |
Deferred Credits and Other Liabilities | 274,421,000 | 74,053,000 |
TOTAL | 4,501,376,000 | 3,919,512,000 |
Commitments and Contingencies | ||
Preferred Stock, Shares Authorized | 1,550,000 | 1,550,000 |
EQUITY | ||
Common Stock, Value, Issued | $ 49,452,000 | $ 49,452,000 |
Additional Paid in Capital, Common Stock | 1,200,125,000 | 1,050,125,000 |
Retained Earnings (Accumulated Deficit) | 1,830,335,000 | 1,541,134,000 |
Total shareholders' equity | 3,079,912,000 | 2,640,711,000 |
Total shareholders' equity | 3,118,662,000 | 2,679,461,000 |
Equity, Attributable to Noncontrolling Interest | 38,750,000 | 38,750,000 |
TOTAL LIABILITIES AND EQUITY | $ 8,056,572,000 | $ 7,043,964,000 |
Common Stock, Shares, Issued | 46,525,000 | 46,525,000 |
Common Stock, Shares Authorized | 200,000,000 | 200,000,000 |
Entergy Texas [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | $ 329,941,000 | $ 115,549,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Investment Owned, Fair Value | 214,000 | 250,000 |
System Energy [Member] | ||
Cash and cash equivalents: | ||
Cash | 60,000 | 78,000 |
Temporary cash investments | 0 | 2,862,000 |
Total cash and cash equivalents | 60,000 | 2,940,000 |
Accounts receivable: | ||
Customer | 54,544,000 | 158,601,000 |
Other | 6,861,000 | 6,145,000 |
Total accounts receivable | 61,405,000 | 164,746,000 |
Public Utilities, Inventory | 155,565,000 | 135,346,000 |
Deferred nuclear refueling outage costs | 8,603,000 | 33,377,000 |
Prepayments and other | 3,373,000 | 9,097,000 |
TOTAL | 229,006,000 | 345,506,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 1,342,317,000 | 1,142,914,000 |
TOTAL | 1,342,317,000 | 1,142,914,000 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 5,495,728,000 | 5,425,449,000 |
Construction work in progress | 130,866,000 | 102,987,000 |
Nuclear fuel | 160,655,000 | 193,004,000 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 5,787,249,000 | 5,721,440,000 |
Less - accumulated depreciation and amortization | 3,493,299,000 | 3,412,257,000 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 2,293,950,000 | 2,309,183,000 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 446,360,000 | 415,121,000 |
Other | 730,000 | 1,422,000 |
Deferred Costs and Other Assets | 447,090,000 | 416,543,000 |
TOTAL ASSETS | 4,312,363,000 | 4,214,146,000 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 57,000 | 300,037,000 |
Accounts Payable | 118,523,000 | 21,701,000 |
Accounts payable | 73,580,000 | 58,178,000 |
Taxes accrued | 27,401,000 | 7,597,000 |
Interest accrued | 12,954,000 | 11,591,000 |
Sale-leaseback/depreciation regulatory liability | 0 | 103,497,000 |
Other | 4,354,000 | 4,071,000 |
TOTAL | 236,869,000 | 506,672,000 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 405,744,000 | 376,070,000 |
Accumulated deferred investment tax credits | 46,960,000 | 44,692,000 |
Regulatory Liability For Income Taxes Net | 107,458,000 | 110,840,000 |
Other regulatory liabilities | 782,912,000 | 665,024,000 |
Asset Retirement Obligations, Noncurrent | 1,084,234,000 | 1,042,461,000 |
Pension and other postretirement liabilities | 19,491,000 | 40,750,000 |
Long-Term Debt, Excluding Current Maturities | 738,402,000 | 477,868,000 |
Deferred Credits and Other Liabilities | 1,754,000 | 2,000 |
TOTAL | 3,186,955,000 | 2,757,707,000 |
Commitments and Contingencies | ||
EQUITY | ||
Common Stock, Value, Issued | 916,850,000 | 1,086,850,000 |
Retained Earnings (Accumulated Deficit) | (28,311,000) | (137,083,000) |
Total shareholders' equity | 888,539,000 | 949,767,000 |
TOTAL LIABILITIES AND EQUITY | $ 4,312,363,000 | $ 4,214,146,000 |
Common Stock, Shares, Issued | 789,350 | 789,350 |
Common Stock, Shares Authorized | 1,000,000 | 1,000,000 |
Common Stock, Par or Stated Value Per Share | $ 0 | $ 0 |
Consolidated Balance Sheets (Pa
Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Securitized Regulatory Transition Assets, Noncurrent | $ 250,830 | $ 282,886 |
Long-Term Transition Bond, Noncurrent | $ 263,007 | $ 292,760 |
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 |
Common Stock, Shares Authorized | 499,000,000 | 499,000,000 |
Common Stock, Shares, Issued | 280,975,348 | 279,653,929 |
Treasury Stock, Common, Shares | 68,126,778 | 68,477,429 |
Entergy New Orleans [Member] | ||
Securitized Regulatory Transition Assets, Noncurrent | $ 506 | $ 13,363 |
Long-Term Transition Bond, Noncurrent | 5,415 | 17,697 |
Entergy Texas [Member] | ||
Securitized Regulatory Transition Assets, Noncurrent | 250,324 | 269,523 |
Long-Term Transition Bond, Noncurrent | $ 257,592 | $ 275,064 |
Common Stock, Shares Authorized | 200,000,000 | 200,000,000 |
Common Stock, Shares, Issued | 46,525,000 | 46,525,000 |
Common Stock, Shares, Outstanding | 46,525,000 | 46,525,000 |
Common Stock, No Par Value | $ 0 | $ 0 |
System Energy [Member] | ||
Common Stock, Par or Stated Value Per Share | $ 0 | $ 0 |
Common Stock, Shares Authorized | 1,000,000 | 1,000,000 |
Common Stock, Shares, Issued | 789,350 | 789,350 |
Common Stock, Shares, Outstanding | 789,350 | 789,350 |
Consolidated Statements Of Chan
Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands | Total | Common Stock [Member] | Additional Paid-in Capital [Member] | Retained Earnings [Member] | AOCI Attributable to Parent [Member] | Subsidiaries Preferred Stock and Noncontrolling Interest [Member] | Treasury Stock, Common [Member] | Entergy Arkansas [Member] | Entergy Arkansas [Member] Member's Equity [Member] | Entergy Arkansas [Member] Noncontrolling Interest [Member] | Entergy Louisiana [Member] | Entergy Louisiana [Member] Member's Equity [Member] | Entergy Louisiana [Member] AOCI Attributable to Parent [Member] | Entergy Louisiana [Member] Noncontrolling Interest [Member] | Entergy Mississippi [Member] | Entergy Mississippi [Member] Member's Equity [Member] | Entergy Mississippi [Member] Noncontrolling Interest [Member] | Entergy New Orleans [Member] | Entergy Texas [Member] | Entergy Texas [Member] Subsidiaries Preferred Stock [Member] | Entergy Texas [Member] Common Stock [Member] | Entergy Texas [Member] Additional Paid-in Capital [Member] | Entergy Texas [Member] Retained Earnings [Member] | System Energy [Member] | System Energy [Member] Common Stock [Member] | System Energy [Member] Retained Earnings [Member] | Entergy Corporation [Member] |
Total shareholders' equity | $ 10,961,142 | $ 2,700 | $ 6,549,923 | $ 9,897,182 | $ (449,207) | $ 35,000 | $ (5,074,456) | $ 3,276,169 | $ 3,276,169 | $ 0 | $ 7,457,688 | $ 7,453,361 | $ 4,327 | $ 0 | $ 1,672,734 | $ 1,672,734 | $ 0 | $ 606,917 | $ 2,157,578 | $ 35,000 | $ 49,452 | $ 955,162 | $ 1,117,964 | $ 1,080,546 | $ 951,850 | $ 128,696 | |
Consolidated net income | 1,118,719 | 0 | 0 | 1,118,492 | 0 | 227 | 0 | 298,484 | 316,576 | (18,092) | 653,984 | 653,984 | 0 | 0 | 166,834 | 166,834 | 0 | 31,798 | 228,824 | 0 | 0 | 0 | 228,824 | 106,814 | 0 | 106,814 | |
Proceeds from Contributions from Parent | 125,000 | 125,000 | 0 | 0 | 95,000 | 0 | 0 | 95,000 | 0 | 0 | |||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | 116,679 | 0 | 0 | 0 | 116,679 | 0 | 0 | 3,951 | 0 | 3,951 | 0 | ||||||||||||||||
Stock Issued During Period, Value, New Issues | 204,214 | 20 | 204,194 | 0 | 0 | 0 | 0 | 3,713 | 3,750 | 0 | (37) | 0 | |||||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | (3,438) | 0 | (3,438) | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | 50,317 | 0 | 15,560 | 0 | 0 | 0 | 34,757 | ||||||||||||||||||||
Dividends, Common Stock, Cash | (775,122) | 0 | 0 | (775,122) | 0 | 0 | 0 | (50,000) | (50,000) | 0 | (60,000) | (60,000) | 0 | 0 | (96,000) | 0 | (96,000) | ||||||||||
Proceeds from Noncontrolling Interests | 51,202 | 0 | 0 | 0 | 0 | 51,202 | 0 | 51,202 | 0 | 51,202 | 0 | ||||||||||||||||
Stockholders' Equity, Other | (51) | (51) | 0 | 0 | |||||||||||||||||||||||
Dividends, Preferred Stock, Cash | (18,319) | 0 | 0 | 0 | 0 | (18,319) | 0 | (1,909) | 0 | 0 | 0 | (1,909) | $ (16,000) | ||||||||||||||
Total shareholders' equity | 11,705,394 | 2,720 | 6,766,239 | 10,240,552 | (332,528) | 68,110 | (5,039,699) | 3,575,855 | 3,542,745 | 33,110 | 8,180,572 | 8,172,294 | 8,278 | 0 | 1,839,568 | 1,839,568 | 0 | 638,715 | 2,483,206 | 38,750 | 49,452 | 1,050,125 | 1,344,879 | 1,091,360 | 951,850 | 139,510 | |
Consolidated net income | 1,097,138 | 0 | 0 | 1,103,166 | 0 | (6,028) | 0 | 292,887 | 297,245 | (4,358) | 855,870 | 854,504 | 0 | 1,366 | 176,267 | 197,622 | (21,355) | 64,101 | 303,327 | 0 | 0 | 0 | 303,327 | (276,593) | 0 | (276,593) | |
Proceeds from Contributions from Parent | 1,000,000 | 1,000,000 | 0 | 0 | 0 | 135,000 | 135,000 | 0 | |||||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | 140,774 | 0 | 0 | 0 | 140,774 | 0 | 0 | 47,092 | 0 | 47,092 | 0 | ||||||||||||||||
Noncontrolling Interest, Increase from Subsidiary Equity Issuance | 31,636 | 0 | 0 | 0 | 0 | 31,636 | 0 | 31,636 | 0 | 0 | 31,636 | ||||||||||||||||
Noncash Capital Contribution from Parent | 3,597 | 3,597 | 0 | 0 | |||||||||||||||||||||||
Stock Issued During Period, Value, New Issues | 861,993 | 77 | 861,916 | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | (9,438) | 0 | (9,438) | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | 74,883 | 0 | 14,178 | 0 | 0 | 0 | 60,705 | ||||||||||||||||||||
Dividends, Common Stock, Cash | (841,677) | 0 | 0 | (841,677) | 0 | 0 | 0 | (86,000) | (86,000) | 0 | (624,000) | (624,000) | 0 | 0 | (105,000) | 0 | 0 | 0 | (105,000) | ||||||||
Proceeds from Noncontrolling Interests | 24,702 | 0 | 0 | 0 | 0 | 24,702 | 0 | 0 | 24,702 | 0 | 24,702 | ||||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (2,194) | 0 | 0 | 0 | 0 | (2,194) | 0 | (927) | 0 | (927) | (1,267) | 0 | 0 | (1,267) | |||||||||||||
Stockholders' Equity, Other | (52) | (52) | 0 | 0 | |||||||||||||||||||||||
Dividends, Preferred Stock, Cash | (18,319) | 0 | 0 | 0 | 0 | (18,319) | 0 | (2,072) | 0 | 0 | 0 | (2,072) | (16,000) | ||||||||||||||
Total shareholders' equity | 13,064,892 | 2,797 | 7,632,895 | 10,502,041 | (191,754) | 97,907 | (4,978,994) | 3,781,815 | 3,753,990 | 27,825 | 9,493,448 | 9,406,343 | 55,370 | 31,735 | 2,040,537 | 2,037,190 | 3,347 | 702,816 | 2,679,461 | 38,750 | 49,452 | 1,050,125 | 1,541,134 | 949,767 | 1,086,850 | (137,083) | |
Consolidated net income | 2,362,310 | 0 | 0 | 2,356,536 | 0 | 5,774 | 0 | 396,850 | 402,081 | (5,231) | 1,273,370 | 1,270,382 | 0 | 2,988 | 181,969 | 192,271 | (10,302) | 228,938 | 291,273 | 0 | 0 | 0 | 291,273 | 108,772 | 0 | 108,772 | |
Proceeds from Contributions from Parent | 1,457,676 | 1,457,676 | 0 | 0 | 150,000 | 0 | 0 | 150,000 | 0 | 0 | |||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | 29,294 | 0 | 0 | 0 | 29,294 | 0 | 0 | (572) | 0 | (572) | 0 | ||||||||||||||||
Noncontrolling Interest, Increase from Subsidiary Equity Issuance | 14,577 | 0 | 0 | 0 | 0 | 14,577 | 0 | 14,577 | 0 | 0 | 14,577 | ||||||||||||||||
Stock Issued During Period, Value, New Issues | 132,417 | 13 | 132,404 | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | (1,768) | 0 | (1,768) | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | 57,376 | 0 | 31,880 | 0 | 0 | 0 | 25,496 | ||||||||||||||||||||
Dividends, Common Stock, Cash | (918,193) | 0 | 0 | (918,193) | 0 | 0 | 0 | (417,000) | (417,000) | 0 | (660,750) | (660,750) | 0 | 0 | (40,000) | (40,000) | 0 | (125,000) | (170,000) | (170,000) | 0 | ||||||
Proceeds from Noncontrolling Interests | 25,708 | 0 | 0 | 0 | 0 | 25,708 | 0 | 0 | 25,708 | 0 | 25,708 | ||||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (5,188) | 0 | 0 | 0 | 0 | (5,188) | 0 | (995) | 0 | (995) | (4,193) | 0 | 0 | (4,193) | |||||||||||||
Stockholders' Equity, Other | (37) | (37) | 0 | 0 | |||||||||||||||||||||||
Dividends, Preferred Stock, Cash | (18,319) | 0 | 0 | 0 | 0 | (18,319) | 0 | (2,072) | 0 | 0 | 0 | (2,072) | $ (16,000) | ||||||||||||||
Total shareholders' equity | $ 14,743,106 | $ 2,810 | $ 7,795,411 | $ 11,940,384 | $ (162,460) | $ 120,459 | $ (4,953,498) | $ 3,760,670 | $ 3,739,071 | $ 21,599 | $ 11,573,519 | $ 11,473,614 | $ 54,798 | $ 45,107 | $ 2,208,214 | $ 2,189,461 | $ 18,753 | $ 806,754 | $ 3,118,662 | $ 38,750 | $ 49,452 | $ 1,200,125 | $ 1,830,335 | $ 888,539 | $ 916,850 | $ (28,311) |
Consolidated Statements Of Ch_2
Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Dividends, Preferred Stock, Cash | $ 18,319 | $ 18,319 | $ 18,319 |
Entergy Corporation [Member] | |||
Dividends, Preferred Stock, Cash | $ 16,000 | $ 16,000 | $ 16,000 |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2023 | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Entergy Arkansas [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Entergy Louisiana [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Entergy Mississippi [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Entergy New Orleans [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Entergy Texas [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
System Energy [Member] | |
Significant Accounting Policies [Text Block] | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by GAAP in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. Certain previously reported amounts in the financial statements have been reclassified to conform to current classification, with no effect on results of operations, financial positions, or cash flows. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Rate And Regulatory Matters
Rate And Regulatory Matters | 12 Months Ended |
Dec. 31, 2023 | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Entergy Arkansas [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Entergy Louisiana [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Entergy Mississippi [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Entergy New Orleans [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Entergy Texas [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
System Energy [Member] | |
Public Utilities Disclosure [Text Block] | RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022: Other Regulatory Assets Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Other Regulatory Liabilities Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 (a) Offset by related asset. (b) As discussed in “ Complaints Against System Energy ” below, there was an additional $103.5 million classified as a current regulatory liability as of December 31, 2022. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. In July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. In the October 2023 settlement agreement filed in the 2023 formula rate plan proceeding, discussed below in “ Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - 2023 Formula Rate Plan Filing”, Entergy Arkansas included recovery of $34.9 million related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain, partially offset by $24.7 million in excess accumulated deferred income taxes from reductions in state income tax rates, each before consideration of their respective tax gross-up. The settlement was approved by the APSC in December 2023. See Note 3 to the financial statements for further discussion of the resolution of the 2016-2018 IRS audit and the State of Arkansas corporate income tax rate changes. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018, the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing. As discussed below in “ Retail Rate Proceedings - Filings with the LPSC (Entergy Louisiana) - Retail Rates - Electric - Formula Rate Plan Global Settlement”, a global settlement resolving the outstanding issues related to the 2017 formula rate plan filing was reached in October 2023 and approved by the LPSC in November 2023. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. In April 2023, Entergy New Orleans completed the bill credits necessary to comply with the 2018 agreement in principle. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that (1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented; (2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets; and (3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider included carrying charges and was in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposed to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. In December 2022 the FERC issued an order addressing the ALJ’s initial decision and denying System Energy’s motion to vacate the initial decision. The FERC disagreed with the ALJ’s determination that $147 million should be credited to customers in the same manner as the excess accumulated deferred income taxes addressed in System Energy’s March 2018 filing, which had included a stated amount of excess accumulated deferred income taxes to be returned pursuant to a specified methodology and had not included any excess accumulated deferred income taxes associated with the decommissioning tax position. Instead, the FERC ordered System Energy to compute the amount of excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy had previously issued a one-time credit for the excess accumulated deferred income taxes associated with the decommissioning tax position, and System Energy believes no further refunds are required under the methodology provided in the order. The FERC fu rther ordered System Energy to submit a compliance filing within 60 days addressing the justness and reasonableness of the Unit Power Sales Agreement, with respect to its provisions for excess accumulated deferred income ta xes. In February 2023, System Energy filed the compliance filing with the FERC, which provided the calculation of the excess accumulated deferred income taxes associated with the decommissioning tax position with consideration for the resolution of the tax position by the IRS. System Energy confirmed that this amount of excess accumulated deferred income taxes had already been credited to customers, and therefore concluded that no further modifications to the Unit Power Sales Agreement are needed to address excess accumulated deferred income taxes associated with the Tax Act. In June 2023 the FERC issued a deficiency letter requesting additional information about the IRS’s resolution of the tax position for 2016 and 2017. In July 2023, System Energy provided the additional information. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redeterminat |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2019 | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Entergy Arkansas [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Entergy Louisiana [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Entergy Mississippi [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Entergy New Orleans [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Entergy Texas [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
System Energy [Member] | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Total income taxes for Entergy differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes generated and reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $372 million as of December 31, 2023 and $372 million as of December 31, 2022 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. Certain accelerated tax deductions which generated taxable losses in various taxing jurisdictions, and which have a limited term carryover period, have resulted in the impairment of the realizability of such carryovers and are reflected in the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. The balances of unrecognized tax benefits include $1,899 million, $3,254 million, and $2,256 million as of December 31, 2023, 2022, and 2021, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $541 million, $3,140 million, and $3,504 million as of December 31, 2023, 2022, and 2021, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2023, 2022, and 2021 accrued balance for the possible payment of interest is approximately $39 million, $50 million, and $52 million, respectively. Interest (net-of-tax) of ($11) million, $8 million, and ($4) million was recorded in 2023, 2022, and 2021, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Utility Restructurings In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans. The IRS also required Entergy New Orleans to reverse a tax gain associated with the 2017 restructuring that had been previously recognized, allowing Entergy New Orleans to reduce its tax expense by $39 million. After the restructuring, Entergy Arkansas adopted a new method of accounting for income tax purposes in which its nuclear decommissioning costs are treated as production costs of electricity includable in cost of goods sold, which resulted in a $1.8 billion reduction in taxable income on its 2018 tax return that was treated as an unrecognized tax benefit. In conjunction with the audit, Entergy agreed with the IRS adjustments concerning the nuclear decommissioning tax position allowing Entergy Arkansas to include $102 million of its decommissioning liability in cost of goods sold. Mark-to-Market Method of Accounting In 2016, Entergy Louisiana elected mark-to-market income tax treatment for various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility and from System Energy under the Unit Power Sales Agreement as well as other intercompany power purchase agreements. The election resulted in a $2 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with the Vidalia contract and various other third-party and intercompany wholesale electric power purchase and sale agreements. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $132 million and a corresponding reduction of income tax expense primarily associated with the effect of the Tax Cuts and Jobs Act rate reduction discussed below. In 2017, Entergy New Orleans also elected mark-to-market income tax treatment for the Unit Power Sales Agreement and various intercompany wholesale electric contracts which resulted in a $1 billion deductible temporary difference. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The net allowance resulted in a reversal of a provision for uncertain tax positions of $139 million and a corresponding reduction of income tax expense. In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “ Regulatory and Other Matters ” section below. Restructuring of Entergy’s Non-Utility Operations Business During the 2016 to 2018 audit period, the ownership of certain of Entergy’s non-utility operations business nuclear power plants (previously reported as part of Entergy Wholesale Commodities) was restructured. Such restructuring transactions required Entergy to recognize the plants’ nuclear decommissioning liabilities for income tax purposes. The accrual of the nuclear decommissioning liabilities also required Entergy to recognize a gain for income tax purposes, a significant portion of which resulted in an increase in the tax basis of the assets. Because certain aspects of the restructuring transactions involved uncertainty, Entergy recorded a provision for uncertain tax positions. The IRS did not propose adjustments to the tax treatment of the restructuring transactions resulting in a net decrease to income tax expense of $288 million from the reversal of the provision for uncertain tax positions in fourth quarter 2023. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Additional customer credits related to the audit outcome may be due in accordance with prior regulatory agreements associated with the Entergy Louisiana and Entergy Gulf States Louisiana business combination and Entergy New Orleans restructuring and general rate-making principles. A regulatory liability and associated regulatory charge of $38 million and $60 million ($28 million and $44 million net-of-tax) were recorded for Entergy Louisiana and Entergy New Orleans, respectively. The inclusion of the effects of the audit on customer rates is subject to the review and approval of the retail |
Revolving Credit Facilities, Li
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings | 12 Months Ended |
Dec. 31, 2023 | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Entergy Arkansas [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Entergy Louisiana [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Entergy Mississippi [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Entergy New Orleans [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Entergy Texas [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
System Energy [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2028. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted-average interest rate for the year ended December 31, 2023 was 6.52% on the drawn portion of the facility. The following is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion. As of December 31, 2023, Entergy Corporation had $1,138.1 million of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2023 was 5.44%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. The FERC-authorized short-term borrowing limit for System Energy is effective through March 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 Vermont Yankee Credit Facility (Entergy Corporation) In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC), Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2024. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2023, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the year ended December 31, 2023 was 6.61% on the drawn portion of the facility. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. As of December 31, 2023, Entergy Arkansas and Entergy Louisiana each has obtained financing authorization from the FERC that extends through April 2025 for issuances by its nuclear fuel company VIEs. System Energy has obtained financing authorization from the FERC that extends through March 2025 for issuances by its nuclear fuel company VIEs. |
Long - Term Debt (Notes)
Long - Term Debt (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Entergy Arkansas [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Entergy Louisiana [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Entergy Mississippi [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Entergy New Orleans [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Entergy Texas [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
System Energy [Member] | |
Long-Term Debt [Text Block] | LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. The FERC-authorized long-term borrowing limit for System Energy is effective through March 2025. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2025. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2025. Long-term debt for the Registrant Subsidiaries as of December 31, 2023 and 2022 consisted of: 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 (a) Consists of pollution control revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The debt is secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 Securitization Bonds Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds in 2024 in the amount of $6.2 million, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in the amount of $54.3 million in 2022, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri In January 2022 the PUCT authorized the issuance of securitization bonds to recover $242.9 million of Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs, plus carrying costs, plus approximately $13.3 million relating to a system restoration regulatory asset related to Hurricane Harvey, plus up-front qualified costs. In April 2022, Entergy Texas Restoration Funding II, LLC, a company wholly-owned and consolidated by Entergy Texas, issued $290.85 million of senior secured system restoration bonds (securitization bonds), as follows: Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding II expects to make principal payments on the securitization bonds over the next four years in the amounts of $18.3 million for 2024, $18.8 million for 2025, $19.4 million for 2026, and $13.4 million for 2027 for Tranche A-1, after which Tranche A-1 will be fully repaid. Entergy Texas Restoration Funding II expects to begin principal payments for Tranche A-2 in 2027 with payments of $6.6 million in 2027 and $20.5 million in 2028. With the proceeds, Entergy Texas Restoration Funding II purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. Entergy Texas expects to use the proceeds to reduce its outstanding debt. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding II, including the transition property, and the creditors of Entergy Texas Restoration Funding II do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding II except to remit system restoration charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Preferred Equity (Notes)
Preferred Equity (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Preferred Equity Disclosure [Text Block] | PREFERRED EQUITY AND NONCONTROLLING INTERESTS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2023 and 2022, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company, LLC (a Utility subsidiary) and Entergy Finance Holding, Inc. (an Entergy subsidiary in the non-utility operations business), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income. |
Entergy Texas [Member] | |
Preferred Equity Disclosure [Text Block] | PREFERRED EQUITY AND NONCONTROLLING INTERESTS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2023 and 2022, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company, LLC (a Utility subsidiary) and Entergy Finance Holding, Inc. (an Entergy subsidiary in the non-utility operations business), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income. |
Entergy Louisiana [Member] | |
Preferred Equity Disclosure [Text Block] | PREFERRED EQUITY AND NONCONTROLLING INTERESTS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2023 and 2022, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company, LLC (a Utility subsidiary) and Entergy Finance Holding, Inc. (an Entergy subsidiary in the non-utility operations business), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income. |
Entergy Mississippi [Member] | |
Preferred Equity Disclosure [Text Block] | PREFERRED EQUITY AND NONCONTROLLING INTERESTS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2023 and 2022, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company, LLC (a Utility subsidiary) and Entergy Finance Holding, Inc. (an Entergy subsidiary in the non-utility operations business), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income. |
Entergy Arkansas [Member] | |
Preferred Equity Disclosure [Text Block] | PREFERRED EQUITY AND NONCONTROLLING INTERESTS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2023 and 2022, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company, LLC (a Utility subsidiary) and Entergy Finance Holding, Inc. (an Entergy subsidiary in the non-utility operations business), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income. |
Common Equity (Notes)
Common Equity (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy Arkansas [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy Louisiana [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy Mississippi [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy New Orleans [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy Texas [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
System Energy [Member] | |
Common Equity Disclosure [Text Block] | COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2023, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $4.34 in 2023, $4.10 in 2022, and $3.86 in 2021. Equity Distribution Program In January 2021, Entergy Corporation entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy Corporation may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy Corporation common stock, Entergy Corporation may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $2 billion. As of December 31, 2023, an aggregate gross sales price of approximately $1.5 billion has been sold under the at market equity distribution program. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. During the years ended December 31, 2023 and 2022, there were no shares of common stock issued under the at the market equity distribution program. In June, August, and October 2021, Entergy Corporation entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid to the forward sellers fees of approximately $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In March, June, and September 2022, Entergy Corporation entered into forward sale agreements for 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares of common stock, respectively. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November 2022. The forward sale agreements required Entergy Corporation to, at its election prior to September 29, 2023 for the March 2022 agreements and prior to December 29, 2023 for the June and September 2022 agreements, either (i) physically settle the transactions by issuing the total of 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $108.12, $116.94, and $115.46 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,538,010 shares, 2,124,086 shares, and 1,666,172 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $168 million, $250.9 million, and $194.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $1.7 million, $2.5 million, and $1.9 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2022, Entergy Corporation physically settled its obligations under the then-outstanding forward sale agreements by delivering 7,688,419 shares of common stock in exchange for cash proceeds of $853.3 million. The forward sale price used to determine the cash proceeds received by Entergy Corporation was calculated based on the initial forward sale price of $112.50 per share as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.7 million of general issuance costs with the settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In June 2023, Entergy Corporation entered into forward sale agreements for 102,995 shares and 365,307 shares of common stock, and in November 2023, Entergy Corporation entered into a forward sale agreement for 853,117 shares of common stock. No amounts were recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occurred in November and December 2023. The forward sale agreements required Entergy Corporation to, at its election prior to May 31, 2024 and June 28, 2024, respectively, for the June 2023 agreements and prior to August 11, 2024 for the November 2023 agreement, either (i) physically settle the transactions by issuing the total of 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $101.36, $101.39, and $97.48 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. Each forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 102,995 shares, 365,307 shares, and 853,117 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $10.5 million, $37.4 million, and $84 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward sellers fees of approximately $0.1 million, $0.4 million, and $0.8 million, respectively, which have not been deducted from the gross sales prices. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In November 2023, Entergy Corporation physically settled its obligations under the June 2023 forward sale agreements, and in December 2023, Entergy Corporation physically settled its obligations under the November 2023 forward sale agreement, by delivering 468,302 shares and 853,117 shares of common stock, respectively, in exchange for cash proceeds of $47.8 million and $83.3 million, respectively. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $101.38 and $97.48 per share, respectively, as adjusted in accordance with the forward sale agreements. Entergy Corporation incurred an aggregate amount of approximately $0.4 million of general issuance costs with the settlements. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt. In December 2023, Entergy Corporation entered into a forward sale agreement for 2,753,246 shares of common stock. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlement of the equity forward sale agreement occurs. The forward sale agreement requires Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transaction by issuing the total of 2,753,246 shares of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially approximately $101.11 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 2,753,246 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $280.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward sellers fees of approximately $2.8 million which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, were determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. At December 31, 2023, 1,762,709 shares under the forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under the then- outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. At December 31, 2022, there were no forward share agreements outstanding. Retained Earnings and Dividends Entergy Corporation received dividend payments and distributions from subsidiaries totaling $189 million in 2023, $301 million in 2022, and $136 million in 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2023 | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Entergy Arkansas [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Entergy Louisiana [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Entergy Mississippi [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Entergy New Orleans [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Entergy Texas [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
System Energy [Member] | |
Commitments and Contingencies Disclosure [Text Block] | COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $100.4 million in 2023, $117.2 million in 2022, and $128.5 million in 2021. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137.4 million in 2024 and a total of $958.8 million for the years 2025 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. See Note 3 to the financial statements for discussion of the effects of the Tax Cuts and Jobs Act and discussion of the resolution of the 2016-2018 IRS audit, which included the tax treatment of the Vidalia contract. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident was available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2023, Entergy Arkansas made a commitment to the APSC to make a filing to forgo its opportunity to seek recovery of the identified costs resulting from the ANO stator incident, specifically all incremental fuel and purchased energy expense, capital and incremental non-fuel operations and maintenance costs, and costs of any judgment that may be rendered against Entergy Arkansas in civil litigation that is not covered by insurance. As a result, in third quarter 2023, Entergy Arkansas recorded write-offs of its regulatory asset for deferred fuel of $68.9 million, which includes interest, and the undepreciated balance of $9.5 million in capital costs related to the ANO stator incident. Consistent with its October 2023 commitment, Entergy Arkansas filed a motion to forgo recovery in November 2023, and the motion was approved by the APSC in December 2023. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and is in partial breach of its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2021, 2022, and 2023 related to Entergy’s nuclear owner/licensee subsidiaries’ litigation with the DOE. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expenses, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expenses. The River Bend damages awarded included $9 million in costs previously recorded as plant, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expenses. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point 2 third round and Indian Point 3 second round combined damages case. Entergy received payment from the U.S. Treasury in January 2022. The effect in 2021 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. In March 2023 the DOE submitted an offer of judgment to resolve claims in the fourth round ANO damages case. The $41 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in April 2023. The effects of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expenses, materials and supplies, and taxes other than income taxes. The ANO damages awarded included $18 million related to costs previously recorded as plant, $10 million related to costs previously recorded as other operation and maintenance expenses, $8 million related to costs previously recorded as nuclear fuel expense, $3 million related to costs previously recorded as materials and supplies, and $2 million related to costs previously recorded as taxes other than income taxes. In July 2023 the DOE submitted an offer of judgment to resolve claims in the Indian Point 2 fourth round and Indian Point 3 third round combined damages case. The $59 million offer was accepted by Entergy and Holtec International, as the current owner. The U.S. Court of Federal Claims issued a final judgment in that amount in favor of Holtec Indian Point 2, LLC and Holtec Indian Point 3, LLC (previously Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC) and against the DOE. Holtec received payment from the U.S. Treasury in July 2023. Consistent with certain terms agreed upon in connection with the sale of Indian Point Energy Center in May 2021, Holtec transferred $40 million to Entergy for its pro-rata share of the litigation proceeds in August 2023. The remainder of the judgment was retained by Holtec. The effect of recording Entergy’s pro-rata share of the judgment was a reduction to asset write-offs, impairments, and related charges (credits). Entergy’s pro-rata share of the damages awarded included $18 million related to costs previously recorded as spending on the asset retirement obligation, $15 million related to costs previously recorded as other operation and maintenance expenses, $6 million related to costs previously recorded as plant, and $1 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $500 million, as of January 1, 2024, for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $15.8 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $165.9 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $829.6 million). This retrospective premium is assessable at approximately $24.7 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $16.3 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g., off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e., contractors)). These coverages also respond to an accident caused by terrorism. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants are in compliance with the financial protection requirements of the NRC. These coverage limits, deductibles, and weekly indemnity periods are subject to change based on results of NEIL loss control inspections. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.06 billion per occurrence at each plant. The property deductible is $20 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from a windstorm for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned nuclear outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks (nuclear and non-nuclear loss); then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks (nuclear and non-nuclear loss); and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period (nuclear loss only). Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage from a nuclear event under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 195 lawsuits involving approximately 345 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. |
Asset Retirement Obligations
Asset Retirement Obligations | 12 Months Ended |
Dec. 31, 2023 | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Entergy Arkansas [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Entergy Louisiana [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Entergy Mississippi [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Entergy New Orleans [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Entergy Texas [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
System Energy [Member] | |
Asset Retirement Obligation Disclosure [Text Block] | ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 As of December 31, 2023 and 2022, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. In third quarter 2023, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a $10.8 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit. In the third quarter 2022, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $5.4 million reduction in its decommissioning cost liability, along with a corresponding reduction in the related asset retirement obligation cost asset that will be depreciated over the remaining life of the unit. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. |
Leases
Leases | 12 Months Ended |
Dec. 31, 2023 | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Entergy Arkansas [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Entergy Louisiana [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Entergy Mississippi [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Entergy New Orleans [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Entergy Texas [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
System Energy [Member] | |
Lessor, Sales-type Leases [Text Block] | LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 Of the lease costs disclosed above, Entergy had $5.0 million and $5.4 million in short-term leases costs for the years ended December 31, 2023 and 2022, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.6 million, Entergy Mississippi had $1.1 million, Entergy New Orleans had $0.1 million, and Entergy Texas had $0.4 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 Of the lease costs disclosed above, Entergy Arkansas had $1.7 million, Entergy Louisiana had $1.8 million, Entergy Mississippi had $0.9 million, Entergy New Orleans had $0.2 million, and Entergy Texas had $0.8 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheets at December 31, 2023 and 2022 are $ 207 million 191 million 84 million 64 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. |
Retirement, Other Postretiremen
Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Entergy Arkansas [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Entergy Louisiana [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Entergy Mississippi [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Entergy New Orleans [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Entergy Texas [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
System Energy [Member] | |
Retirement Benefits [Text Block] | RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— (a) Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $5.6 billion and $5.7 billion at December 31, 2023 and 2022, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $43.8 million in 2023, $30.9 million in 2022, and $28.6 million in 2021. In 2023, 2022, and 2021, Entergy recognized $27.9 million, $12.2 million, and $10.9 million, respectively, in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $88.6 million as of December 31, 2023 of which $13.8 million was a current liability and $74.8 million was a non-current liability. The projected benefit obligation was $152.4 million as of December 31, 2022 of which $62.4 million was a current liability and $90 million was a non-current liability. The accumulated benefit obligation was $77.9 million and $140 million as of December 31, 2023 and 2022, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($29.7 million at December 31, 2023 and $56.8 million at December 31, 2022) and accumulated other comprehensive income before taxes ($3.9 million at December 31, 2023 and $8.7 million at Decemb |
Stock-Based Compensation
Stock-Based Compensation | 12 Months Ended |
Dec. 31, 2023 | |
Share-Based Payment Arrangement, Noncash Expense [Abstract] | |
Share-Based Payment Arrangement [Text Block] | STOCK-BASED COMPENSATION (Entergy Corporation) Entergy grants stock options, restricted stock, performance units, and restricted stock units to key employees of the Entergy subsidiaries under its equity plans which are shareholder-approved stock-based compensation plans. Effective May 3, 2019, Entergy’s shareholders approved the 2019 Omnibus Incentive Plan (2019 Plan). The maximum number of common shares that can be issued from the 2019 Plan for stock-based awards is 12,200,000 all of which are available for incentive stock option grants. The 2019 Plan applies to awards granted on or after May 3, 2019 and awards expire ten years from the date of grant. As of December 31, 2023, there were 7,546,825 authorized shares remaining for stock-based awards. Stock Options Stock options are granted at exercise prices that equal the closing market price of Entergy Corporation common stock on the date of grant. Generally, stock options granted will become exercisable in equal amounts on each of the first three anniversaries of the date of grant. Unless they are forfeited previously under the terms of the grant, options expire 10 years after the date of the grant if they are not exercised. The following table includes financial information for stock options for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $4.1 $4.2 $4.2 Tax benefit recognized in Entergy’s consolidated net income $1.1 $1.1 $1.1 Compensation cost capitalized as part of fixed assets and materials and supplies $1.9 $1.7 $1.5 Entergy determines the fair value of the stock option grants by considering factors such as lack of marketability, stock retention requirements, and regulatory restrictions on exercisability in accordance with accounting standards. The stock option weighted-average assumptions used in determining the fair values are as follows: 2023 2022 2021 Stock price volatility 24.89% 24.27% 23.93% Expected term in years 6.89 6.92 6.93 Risk-free interest rate 3.51% 1.77% 0.74% Dividend yield 4.00% 4.00% 4.00% Dividend payment per share $4.34 $4.10 $3.86 Stock price volatility is calculated based upon the daily public stock price volatility of Entergy Corporation common stock over a period equal to the expected term of the award. The expected term of the options is based upon historical option exercises and the weighted-average life of options when exercised and the estimated weighted-average life of all vested but unexercised options. In 2008, Entergy implemented stock ownership guidelines for its senior executive officers. These guidelines require an executive officer to own shares of Entergy Corporation common stock equal to a specified multiple of his or her salary. Until an executive officer achieves this ownership position the executive officer is required to retain 75% of the net-of-tax net profit upon exercise of the option to be held in Entergy Corporation common stock. The reduction in fair value of the stock options due to this restriction is based upon an estimate of the call option value of the reinvested gain discounted to present value over the applicable reinvestment period. A summary of stock option activity for the year ended December 31, 2023 and changes during the year are presented below: Number of Options Weighted- Aggregate Intrinsic Value Weighted- Options outstanding as of January 1, 2023 2,776,355 $96.30 Options granted 281,874 $108.47 Options exercised (111,929) $85.69 Options forfeited/expired (47,592) $110.40 Options outstanding as of December 31, 2023 2,898,708 $97.66 $31,447,529 5.66 Options exercisable as of December 31, 2023 2,191,916 $94.94 $30,475,161 4.83 Weighted-average grant-date fair value of options granted during 2023 $20.07 The weighted-average grant-date fair value of options granted during the year was $16.25 for 2022 and $12.27 for 2021. The total intrinsic value of stock options exercised was $2 million during 2023, $20 million during 2022, and $2 million during 2021. The intrinsic value, which has no effect on net income, of the outstanding stock options exercised is calculated by the positive difference between the weighted-average exercise price of the stock options granted and Entergy Corporation’s common stock price as of December 31, 2023. The aggregate intrinsic value of the stock options outstanding as of December 31, 2023 was $31.4 million. Stock options outstanding as of December 31, 2023 includes 1,153,596 out of the money options with an intrinsic value of zero. Entergy recognizes compensation cost over the vesting period of the options based on their grant-date fair value. The total fair value of options that vested was approximately $6 million during 2023, $6 million during 2022, and $5 million during 2021. Cash received from option exercises was $10 million for the year ended December 31, 2023. The tax benefits realized from options exercised was $0.5 million for the year ended December 31, 2023. The following table summarizes information about stock options outstanding as of December 31, 2023: Options Outstanding Options Exercisable Range of Exercise Price As of December 31, 2023 Weighted-Average Remaining Contractual Life-Yrs. Weighted-Average Exercise Price Number Exercisable as of December 31, 2023 Weighted-Average Exercise Price $63.17 - $79.99 772,974 3.18 $73.58 772,974 $73.58 $80.00 - $99.99 972,138 5.45 $92.30 814,286 $91.61 $100.00 - $119.99 685,327 8.48 $109.14 136,387 $109.59 $120.00 - $131.72 468,269 6.08 $131.72 468,269 $131.72 $63.17 - $131.72 2,898,708 5.66 $97.66 2,191,916 $94.94 Stock-based compensation cost related to non-vested stock options outstanding as of December 31, 2023 not yet recognized is approximately $5 million and is expected to be recognized over a weighted-average period of 1.6 years. Restricted Stock Awards Entergy grants restricted stock awards earned under its stock benefit plans in the form of stock units. One-third of the restricted stock awards will vest upon each anniversary of the grant date and are expensed ratably over the three-year vesting period. Shares of restricted stock have the same dividend and voting rights as other common stock and are considered issued and outstanding shares of Entergy upon vesting. In January 2023 the Board approved and Entergy granted 345,983 restricted stock awards under the 2019 Plan. The restricted stock awards were made effective on January 26, 2023 and were valued at $108.47 per share, which was the closing price of Entergy Corporation’s common stock on that date. The following table includes information about the restricted stock awards outstanding as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 607,723 $107.55 Granted 373,741 $108.35 Vested (294,145) $110.54 Forfeited (60,546) $105.64 Outstanding shares at December 31, 2023 626,773 $106.80 The following table includes financial information for restricted stock for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $22.2 $23.2 $24.7 Tax benefit recognized in Entergy’s consolidated net income $5.7 $5.9 $6.3 Compensation cost capitalized as part of fixed assets and materials and supplies $9.7 $9.2 $9.3 The total fair value of the restricted stock awards granted was $41 million, $39 million, and $40 million for the years ended December 31, 2023, 2022, and 2021, respectively. The total fair value of the restricted stock awards vested was $33 million, $34 million, and $32 million for the years ended December 31, 2023, 2022, and 2021, respectively. Long-Term Performance Unit Program Entergy grants long-term incentive awards earned under its stock benefit plans in the form of performance units, which represents the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. The Long-Term Performance Unit Program specifies a minimum, target, and maximum achievement level, the achievement of which will determine the number of performance units that may be earned. Entergy measures performance by assessing Entergy’s total shareholder return relative to the total shareholder return of the companies in the Philadelphia Utility Index. To emphasize the importance of strong cash generation for the long-term health of its business, a credit measure – adjusted funds from operations/debt ratio – was selected as one of the performance measures for the 2023-2025 performance period. For the 2023-2025 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure. In January 2023 the Board approved and Entergy granted 143,212 performance units under the 2019 Plan. The performance units were granted on January 26, 2023, and eighty percent were valued at $130.65 per share based on various factors, primarily market conditions; and twenty percent were valued at $108.47 per share, the closing price of Entergy Corporation’s common stock on that date. Performance units have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the 3-year vesting period, and compensation cost for the portion of the award based on the selected credit measure will be adjusted based on the number of units that ultimately vest. The following table includes information about the long-term performance units outstanding at the target level as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 521,838 $129.94 Granted 156,627 $126.39 Vested (38,150) $162.14 Forfeited (159,314) $145.35 Outstanding shares at December 31, 2023 481,001 $121.12 The following table includes financial information for the long-term performance units for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $11.1 $16.0 $14.5 Tax benefit recognized in Entergy’s consolidated net income $2.8 $4.1 $3.7 Compensation cost capitalized as part of fixed assets and materials and supplies $5.2 $6.7 $5.8 The total fair value of the long-term performance units granted was $20 million, $35 million, and $32 million for the years ended December 31, 2023, 2022, and 2021, respectively. In January 2023, Entergy issued 38,150 shares of Entergy Corporation common stock at a share price of $107.59 for awards earned and dividends accrued under the 2020-2022 Long-Term Performance Unit Program. In January 2022, Entergy issued 224,334 shares of Entergy Corporation common stock at a share price of $110.35 for awards earned and dividends accrued under the 2019-2021 Long-Term Performance Unit Program. In January 2021, Entergy issued 235,983 shares of Entergy Corporation common stock at a share price of $95.12 for awards earned and dividends accrued under the 2018-2020 Long-Term Performance Unit Program. Restricted Stock Unit Awards Entergy grants restricted stock unit awards earned under its stock benefit plans in the form of stock units that are subject to time-based restrictions. The restricted stock units may be settled in shares of Entergy Corporation common stock or the cash value of shares of Entergy Corporation common stock at the time of vesting. The costs of restricted stock unit awards are charged to income over the restricted period, which varies from grant to grant. The average vesting period for restricted stock unit awards granted is 38 months. As of December 31, 2023, there were 139,500 unvested restricted stock units that are expected to vest over an average period of 20 months. The following table includes information about the restricted stock unit awards outstanding as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 132,407 $105.75 Granted 22,547 $102.05 Vested (6,142) $110.33 Forfeited (9,312) $103.37 Outstanding shares at December 31, 2023 139,500 $105.11 The following table includes financial information for restricted stock unit awards for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $2.8 $2.0 $1.9 Tax benefit recognized in Entergy’s consolidated net income $0.7 $0.5 $0.5 Compensation cost capitalized as part of fixed assets and materials and supplies $1.2 $0.8 $0.7 The total fair value of the restricted stock unit awards granted was $2 million, $8 million, and $4 million for the years ended December 31, 2023, 2022, and 2021, respectively. The total fair value of the restricted stock unit awards vested was $1 million, $3 million, and $3 million for the years ended December 31, 2023, 2022, and 2021, respectively. |
Business Segment Information (N
Business Segment Information (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Entergy Arkansas [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Entergy Louisiana [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Entergy Mississippi [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Entergy New Orleans [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Entergy Texas [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
System Energy [Member] | |
Segment Reporting Disclosure [Text Block] | BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana. The Utility segment reflects management’s primary basis of organization with a predominant focus on its utility operations in the Gulf South. Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business which owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers and also provides decommissioning services to nuclear power plants owned by non-affiliated entities in the United States. Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 Eliminations are primarily intersegment activity. As of December 31, 2023, all of Entergy’s goodwill is related to the Utility segment. As of December 31, 2022 and 2021, almost all of Entergy’s goodwill was related to the Utility segment. Results of operations for 2023 include: (1) a $568 million reduction, recorded at Utility, and a $275 million reduction, recorded at Parent & Other, in income tax expense as a result of the resolution of the 2016-2018 IRS audit, partially offset by $98 million ($72 million net-of-tax) of regulatory charges, recorded at Utility, to reflect credits expected to be provided to customers by Entergy Louisiana and Entergy New Orleans as a result of the resolution of the 2016-2018 IRS audit; (2) the reversal of a $106 million regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act, recorded at Utility, as part of the settlement of Entergy Louisiana’s test year 2017 formula rate plan filing; (3) a $129 million reduction in income tax expense as a result of the Hurricane Ida securitization in March 2023, which also resulted in a $103 million ($76 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (4) write-offs of $78 million ($59 million net-of-tax), recorded at Utility, as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident. See Note 3 to the financial statements for discussion of the resolution of the 2016-2018 IRS audit. See Note 2 to the financial statements for discussion of the Entergy Louisiana formula rate plan global settlement. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana March 2023 storm cost securitization. See Note 8 to the financial statements for discussion of the ANO stator incident and the approved motion to forgo recovery. Results of operations for 2022 include : (1) a regulatory charge of $551 million ($413 million net-of-tax), recorded at Utility, as a result of System Energy’s partial settlement agreement and offer of settlement related to pending proceedings before the FERC; ( 2) a $283 million reduction in income tax expense as a result of the Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida May 2022 securitization financing, which also resulted in a $224 million ($165 million net-of-tax) regulatory charge, recorded at Utility, to reflect Entergy Louisiana’s obligation to provide credits to its customers as described in an LPSC ancillary order issued as part of the securitization regulatory proceeding; and (3) a gain of $166 million ($130 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Palisades plant in June 2022. See Note 2 to the financial statements for discussion of the System Energy settlement agreement with the MPSC. See Notes 2 and 3 to the financial statements for discussion of the Entergy Louisiana May 2022 storm cost securitization. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax), reflected in “Asset write-offs, impairments, and related charges (credits),” as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center. Change in Reportable Segments Effective January 1, 2023 Entergy completed its multi-year strategy to exit the merchant nuclear power business in 2022 and upon completion of all transition activities, effective January 1, 2023, Entergy Wholesale Commodities is no longer a reportable segment. Remaining business activity previously reported under Entergy Wholesale Commodities is now reported under Parent & Other. Historical segment financial information presented herein has been restated for 2022 and 2021 to reflect the change in reportable segments. The change in reportable segments had no effect on Entergy’s consolidated financial statements or historical segment financial information for the Utility reportable segment. The Fitzpatrick plant was sold to Exelon in March 2017. The Vermont Yankee plant was sold to NorthStar in January 2019. The Pilgrim plant was sold to Holtec International in August 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International in May 2021. The Palisades plant was sold to Holtec International in June 2022. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in Entergy’s consolidated income statements. As the exit from the merchant nuclear power business was completed in 2022, there were no restructuring charges recorded in 2023. Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— In addition, a gain of $166 million was recorded in 2022 as a result of the sale of the Palisades plant and a charge of $340 million was recorded in 2021 as a result of the sale of the Indian Point Energy Center, both reflected in “Asset write-offs, impairments, and related charges (credits)” in Entergy’s consolidated income statements. See Note 14 to the financial statements for discussion of the sale of the Palisades plant and the Indian Point Energy Center. Geographic Areas For the years ended December 31, 2023, 2022, and 2021, Entergy derived no revenue from outside of the United States. As of December 31, 2023 and 2022, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. |
Business Combinations and Asset
Business Combinations and Asset Acquisitions (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Mergers, Acquisitions and Dispositions Disclosures [Text Block] | ACQUISITIONS AND DISPOSITIONS (Entergy Corporation, Entergy Arkansas, Entergy Mississippi, and Entergy Texas) Acquisitions Walnut Bend Solar In June 2020, Entergy Arkansas signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic energy facility, Walnut Bend Solar facility, to be sited on approximately 1,000 acres in Lee County, Arkansas. Acquisition of the Walnut Bend Solar facility was initially approved by the APSC in July 2021. The agreement was amended by the parties in February 2023 and the revised agreement was approved by the APSC in July 2023. In February 2024, Entergy Arkansas made an initial payment of $170 million to acquire the facility. The project will achieve commercial operation once testing is completed and the project has achieved substantial completion. Entergy Arkansas currently expects the project to achieve commercial operation in the first half of 2024, at which time a substantial completion payment of approximately $20 million is expected. Sunflower Solar In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in MS Sunflower Partnership, LLC. Searcy Solar In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which included a final payment of $1 million made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Dispositions Palisades In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site. In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC issued an order approving the application in December 2021. Palisades was shut down in May 2022 and defueled in June 2022. The Palisades transaction closed in June 2022 for a purchase price of $1,000 (subject to adjustment for net liabilities and other amounts). The sale included the transfer of the Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter 2022. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $552 million, and the disposition-date fair value of the asset retirement obligation was approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies. Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plants to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million, and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. |
Entergy Arkansas [Member] | |
Mergers, Acquisitions and Dispositions Disclosures [Text Block] | ACQUISITIONS AND DISPOSITIONS (Entergy Corporation, Entergy Arkansas, Entergy Mississippi, and Entergy Texas) Acquisitions Walnut Bend Solar In June 2020, Entergy Arkansas signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic energy facility, Walnut Bend Solar facility, to be sited on approximately 1,000 acres in Lee County, Arkansas. Acquisition of the Walnut Bend Solar facility was initially approved by the APSC in July 2021. The agreement was amended by the parties in February 2023 and the revised agreement was approved by the APSC in July 2023. In February 2024, Entergy Arkansas made an initial payment of $170 million to acquire the facility. The project will achieve commercial operation once testing is completed and the project has achieved substantial completion. Entergy Arkansas currently expects the project to achieve commercial operation in the first half of 2024, at which time a substantial completion payment of approximately $20 million is expected. Sunflower Solar In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in MS Sunflower Partnership, LLC. Searcy Solar In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which included a final payment of $1 million made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Dispositions Palisades In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site. In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC issued an order approving the application in December 2021. Palisades was shut down in May 2022 and defueled in June 2022. The Palisades transaction closed in June 2022 for a purchase price of $1,000 (subject to adjustment for net liabilities and other amounts). The sale included the transfer of the Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter 2022. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $552 million, and the disposition-date fair value of the asset retirement obligation was approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies. Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plants to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million, and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. |
Entergy Mississippi [Member] | |
Mergers, Acquisitions and Dispositions Disclosures [Text Block] | ACQUISITIONS AND DISPOSITIONS (Entergy Corporation, Entergy Arkansas, Entergy Mississippi, and Entergy Texas) Acquisitions Walnut Bend Solar In June 2020, Entergy Arkansas signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic energy facility, Walnut Bend Solar facility, to be sited on approximately 1,000 acres in Lee County, Arkansas. Acquisition of the Walnut Bend Solar facility was initially approved by the APSC in July 2021. The agreement was amended by the parties in February 2023 and the revised agreement was approved by the APSC in July 2023. In February 2024, Entergy Arkansas made an initial payment of $170 million to acquire the facility. The project will achieve commercial operation once testing is completed and the project has achieved substantial completion. Entergy Arkansas currently expects the project to achieve commercial operation in the first half of 2024, at which time a substantial completion payment of approximately $20 million is expected. Sunflower Solar In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in MS Sunflower Partnership, LLC. Searcy Solar In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which included a final payment of $1 million made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Dispositions Palisades In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site. In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC issued an order approving the application in December 2021. Palisades was shut down in May 2022 and defueled in June 2022. The Palisades transaction closed in June 2022 for a purchase price of $1,000 (subject to adjustment for net liabilities and other amounts). The sale included the transfer of the Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter 2022. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $552 million, and the disposition-date fair value of the asset retirement obligation was approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies. Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plants to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million, and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. |
Entergy Texas [Member] | |
Mergers, Acquisitions and Dispositions Disclosures [Text Block] | ACQUISITIONS AND DISPOSITIONS (Entergy Corporation, Entergy Arkansas, Entergy Mississippi, and Entergy Texas) Acquisitions Walnut Bend Solar In June 2020, Entergy Arkansas signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic energy facility, Walnut Bend Solar facility, to be sited on approximately 1,000 acres in Lee County, Arkansas. Acquisition of the Walnut Bend Solar facility was initially approved by the APSC in July 2021. The agreement was amended by the parties in February 2023 and the revised agreement was approved by the APSC in July 2023. In February 2024, Entergy Arkansas made an initial payment of $170 million to acquire the facility. The project will achieve commercial operation once testing is completed and the project has achieved substantial completion. Entergy Arkansas currently expects the project to achieve commercial operation in the first half of 2024, at which time a substantial completion payment of approximately $20 million is expected. Sunflower Solar In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in MS Sunflower Partnership, LLC. Searcy Solar In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which included a final payment of $1 million made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Dispositions Palisades In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site. In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC issued an order approving the application in December 2021. Palisades was shut down in May 2022 and defueled in June 2022. The Palisades transaction closed in June 2022 for a purchase price of $1,000 (subject to adjustment for net liabilities and other amounts). The sale included the transfer of the Palisades nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a gain of $166 million ($130 million net-of-tax) in the second quarter 2022. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $552 million, and the disposition-date fair value of the asset retirement obligation was approximately $708 million. The transaction also included property, plant, and equipment with a net book value of zero and materials and supplies. Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plants to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million, and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. |
Risk Management And Fair Values
Risk Management And Fair Values (Notes) | 12 Months Ended |
Dec. 31, 2023 | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Entergy Arkansas [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Entergy Louisiana [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Entergy Mississippi [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Entergy New Orleans [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Entergy Texas [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
System Energy [Member] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s non-utility operations’ core business as a wholesale generator was selling energy, measured in MWh, to its customers. The non-utility operations business entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, the non-utility operations business used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. As discussed above, the non-utility operations business’ portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contract in the portfolio. Prior to the expiration of the non-utility operations business’ portfolio of derivative instruments, Entergy may have effectively liquidated a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation would have continued to be deferred in other comprehensive income until they were included in income as the original hedged transaction occurred. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract were recorded as assets or liabilities on the balance sheet and offset as they flowed through to earnings. The non-utility operations business recognized a gain of $2 million in other comprehensive income and reclassified a gain of $ 40 million The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO. The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input Transaction Type Position Change to Input Effect on Fair Value Unit contingent discount Electricity swaps Sell Increase (Decrease) Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 Entergy Louisiana 2023 Level 1 Leve |
Decommissioning Trust Funds
Decommissioning Trust Funds | 12 Months Ended |
Dec. 31, 2023 | |
Decommissioning Trust Fund [Text Block] | DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. As discussed in Note 14 to the financial statements, in June 2022, Entergy completed the sale of Palisades to Holtec. As part of the transaction, Entergy transferred the Palisades decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $552 million. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $591 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $1,770 $19 $134 2022 Debt Securities $1,655 $4 $201 As of December 31, 2023 and 2022, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $1,885 million as of December 31, 2023 and $1,852 million as of December 31, 2022. As of December 31, 2023, available-for-sale debt securities had an average coupon rate of approximately 3.48%, an average duration of approximately 6.36 years, and an average maturity of approximately 10.82 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $134 $6 $840 $63 More than 12 months 999 128 666 138 Total $1,133 $134 $1,506 $201 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $82 $62 1 year - 5 years 517 520 5 years - 10 years 504 461 10 years - 15 years 121 117 15 years - 20 years 179 161 20 years+ 367 334 Total $1,770 $1,655 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $661 million, $889 million, and $1,465 million, respectively. During the year ended December 31, 2023, there were gross gains of $1 million and gross losses of $37 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $2 million and $29 million, respectively, and gross losses of $46 million and $17 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $496.9 $2.4 $53.6 2022 Debt Securities $470.7 $0.2 $69.3 The amortized cost of available-for-sale debt securities was $548.1 million as of December 31, 2023 and $539.8 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 2.66%, an average duration of approximately 6.02 years, and an average maturity of approximately 7.64 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $175 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $22.5 $0.4 $197.6 $18.8 More than 12 months 403.4 53.2 260.1 50.5 Total $425.9 $53.6 $457.7 $69.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $45.3 $21.2 1 year - 5 years 132.2 159.7 5 years - 10 years 205.7 191.7 10 years - 15 years 39.9 38.0 15 years - 20 years 49.6 42.6 20 years+ 24.2 17.5 Total $496.9 $470.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $28.5 million, $42.1 million, and $57.6 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.1 million and gross losses of $2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.1 million and $2.5 million, respectively, and gross losses of $2.6 million and $0.6 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $788.1 $11.7 $37.4 2022 Debt Securities $725.1 $3.5 $67.5 The amortized cost of available-for-sale debt securities was $813.9 million as of December 31, 2023 and $789.1 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.91%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.16 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $251.3 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $69.8 $0.9 $409.9 $24.6 More than 12 months 356.1 36.5 207.5 42.9 Total $425.9 $37.4 $617.4 $67.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $31.4 $33.6 1 year - 5 years 181.6 159.1 5 years - 10 years 170.0 161.7 10 years - 15 years 70.2 67.1 15 years - 20 years 90.2 83.3 20 years+ 244.7 220.3 Total $788.1 $725.1 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $318.6 million, $362.2 million, and $303.4 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.5 million and gross losses of $20.9 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $1.3 million and $6.8 million, respectively, and gross losses of $23 million and $4.1 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $485.2 $4.5 $42.5 2022 Debt Securities $459.7 $0.7 $63.7 The amortized cost of available-for-sale debt securities was $523.2 million as of December 31, 2023 and $522.7 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.44 years, and an average maturity of approximately 10.27 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $164.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.1 $4.5 $231.9 $19.2 More than 12 months 239.1 38.0 198.0 44.5 Total $281.2 $42.5 $429.9 $63.7 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $5.3 $6.8 1 year - 5 years 203.4 201.7 5 years - 10 years 128.6 107.1 10 years - 15 years 10.7 11.7 15 years - 20 years 38.8 35.0 20 years+ 98.4 97.4 Total $485.2 $459.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $314.3 million, $209.4 million, and $513.8 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.6 million and gross losses of $14.2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.2 million and $9.3 million, respectively, and gross losses of $10.7 million and $4 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. |
Entergy Arkansas [Member] | |
Decommissioning Trust Fund [Text Block] | DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. As discussed in Note 14 to the financial statements, in June 2022, Entergy completed the sale of Palisades to Holtec. As part of the transaction, Entergy transferred the Palisades decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $552 million. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $591 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $1,770 $19 $134 2022 Debt Securities $1,655 $4 $201 As of December 31, 2023 and 2022, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $1,885 million as of December 31, 2023 and $1,852 million as of December 31, 2022. As of December 31, 2023, available-for-sale debt securities had an average coupon rate of approximately 3.48%, an average duration of approximately 6.36 years, and an average maturity of approximately 10.82 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $134 $6 $840 $63 More than 12 months 999 128 666 138 Total $1,133 $134 $1,506 $201 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $82 $62 1 year - 5 years 517 520 5 years - 10 years 504 461 10 years - 15 years 121 117 15 years - 20 years 179 161 20 years+ 367 334 Total $1,770 $1,655 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $661 million, $889 million, and $1,465 million, respectively. During the year ended December 31, 2023, there were gross gains of $1 million and gross losses of $37 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $2 million and $29 million, respectively, and gross losses of $46 million and $17 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $496.9 $2.4 $53.6 2022 Debt Securities $470.7 $0.2 $69.3 The amortized cost of available-for-sale debt securities was $548.1 million as of December 31, 2023 and $539.8 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 2.66%, an average duration of approximately 6.02 years, and an average maturity of approximately 7.64 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $175 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $22.5 $0.4 $197.6 $18.8 More than 12 months 403.4 53.2 260.1 50.5 Total $425.9 $53.6 $457.7 $69.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $45.3 $21.2 1 year - 5 years 132.2 159.7 5 years - 10 years 205.7 191.7 10 years - 15 years 39.9 38.0 15 years - 20 years 49.6 42.6 20 years+ 24.2 17.5 Total $496.9 $470.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $28.5 million, $42.1 million, and $57.6 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.1 million and gross losses of $2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.1 million and $2.5 million, respectively, and gross losses of $2.6 million and $0.6 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $788.1 $11.7 $37.4 2022 Debt Securities $725.1 $3.5 $67.5 The amortized cost of available-for-sale debt securities was $813.9 million as of December 31, 2023 and $789.1 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.91%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.16 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $251.3 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $69.8 $0.9 $409.9 $24.6 More than 12 months 356.1 36.5 207.5 42.9 Total $425.9 $37.4 $617.4 $67.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $31.4 $33.6 1 year - 5 years 181.6 159.1 5 years - 10 years 170.0 161.7 10 years - 15 years 70.2 67.1 15 years - 20 years 90.2 83.3 20 years+ 244.7 220.3 Total $788.1 $725.1 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $318.6 million, $362.2 million, and $303.4 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.5 million and gross losses of $20.9 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $1.3 million and $6.8 million, respectively, and gross losses of $23 million and $4.1 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $485.2 $4.5 $42.5 2022 Debt Securities $459.7 $0.7 $63.7 The amortized cost of available-for-sale debt securities was $523.2 million as of December 31, 2023 and $522.7 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.44 years, and an average maturity of approximately 10.27 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $164.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.1 $4.5 $231.9 $19.2 More than 12 months 239.1 38.0 198.0 44.5 Total $281.2 $42.5 $429.9 $63.7 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $5.3 $6.8 1 year - 5 years 203.4 201.7 5 years - 10 years 128.6 107.1 10 years - 15 years 10.7 11.7 15 years - 20 years 38.8 35.0 20 years+ 98.4 97.4 Total $485.2 $459.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $314.3 million, $209.4 million, and $513.8 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.6 million and gross losses of $14.2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.2 million and $9.3 million, respectively, and gross losses of $10.7 million and $4 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. |
Entergy Louisiana [Member] | |
Decommissioning Trust Fund [Text Block] | DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. As discussed in Note 14 to the financial statements, in June 2022, Entergy completed the sale of Palisades to Holtec. As part of the transaction, Entergy transferred the Palisades decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $552 million. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $591 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $1,770 $19 $134 2022 Debt Securities $1,655 $4 $201 As of December 31, 2023 and 2022, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $1,885 million as of December 31, 2023 and $1,852 million as of December 31, 2022. As of December 31, 2023, available-for-sale debt securities had an average coupon rate of approximately 3.48%, an average duration of approximately 6.36 years, and an average maturity of approximately 10.82 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $134 $6 $840 $63 More than 12 months 999 128 666 138 Total $1,133 $134 $1,506 $201 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $82 $62 1 year - 5 years 517 520 5 years - 10 years 504 461 10 years - 15 years 121 117 15 years - 20 years 179 161 20 years+ 367 334 Total $1,770 $1,655 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $661 million, $889 million, and $1,465 million, respectively. During the year ended December 31, 2023, there were gross gains of $1 million and gross losses of $37 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $2 million and $29 million, respectively, and gross losses of $46 million and $17 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $496.9 $2.4 $53.6 2022 Debt Securities $470.7 $0.2 $69.3 The amortized cost of available-for-sale debt securities was $548.1 million as of December 31, 2023 and $539.8 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 2.66%, an average duration of approximately 6.02 years, and an average maturity of approximately 7.64 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $175 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $22.5 $0.4 $197.6 $18.8 More than 12 months 403.4 53.2 260.1 50.5 Total $425.9 $53.6 $457.7 $69.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $45.3 $21.2 1 year - 5 years 132.2 159.7 5 years - 10 years 205.7 191.7 10 years - 15 years 39.9 38.0 15 years - 20 years 49.6 42.6 20 years+ 24.2 17.5 Total $496.9 $470.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $28.5 million, $42.1 million, and $57.6 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.1 million and gross losses of $2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.1 million and $2.5 million, respectively, and gross losses of $2.6 million and $0.6 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $788.1 $11.7 $37.4 2022 Debt Securities $725.1 $3.5 $67.5 The amortized cost of available-for-sale debt securities was $813.9 million as of December 31, 2023 and $789.1 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.91%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.16 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $251.3 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $69.8 $0.9 $409.9 $24.6 More than 12 months 356.1 36.5 207.5 42.9 Total $425.9 $37.4 $617.4 $67.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $31.4 $33.6 1 year - 5 years 181.6 159.1 5 years - 10 years 170.0 161.7 10 years - 15 years 70.2 67.1 15 years - 20 years 90.2 83.3 20 years+ 244.7 220.3 Total $788.1 $725.1 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $318.6 million, $362.2 million, and $303.4 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.5 million and gross losses of $20.9 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $1.3 million and $6.8 million, respectively, and gross losses of $23 million and $4.1 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $485.2 $4.5 $42.5 2022 Debt Securities $459.7 $0.7 $63.7 The amortized cost of available-for-sale debt securities was $523.2 million as of December 31, 2023 and $522.7 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.44 years, and an average maturity of approximately 10.27 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $164.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.1 $4.5 $231.9 $19.2 More than 12 months 239.1 38.0 198.0 44.5 Total $281.2 $42.5 $429.9 $63.7 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $5.3 $6.8 1 year - 5 years 203.4 201.7 5 years - 10 years 128.6 107.1 10 years - 15 years 10.7 11.7 15 years - 20 years 38.8 35.0 20 years+ 98.4 97.4 Total $485.2 $459.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $314.3 million, $209.4 million, and $513.8 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.6 million and gross losses of $14.2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.2 million and $9.3 million, respectively, and gross losses of $10.7 million and $4 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. |
System Energy [Member] | |
Decommissioning Trust Fund [Text Block] | DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. As discussed in Note 14 to the financial statements, in June 2022, Entergy completed the sale of Palisades to Holtec. As part of the transaction, Entergy transferred the Palisades decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $552 million. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $591 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $1,770 $19 $134 2022 Debt Securities $1,655 $4 $201 As of December 31, 2023 and 2022, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $1,885 million as of December 31, 2023 and $1,852 million as of December 31, 2022. As of December 31, 2023, available-for-sale debt securities had an average coupon rate of approximately 3.48%, an average duration of approximately 6.36 years, and an average maturity of approximately 10.82 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $134 $6 $840 $63 More than 12 months 999 128 666 138 Total $1,133 $134 $1,506 $201 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $82 $62 1 year - 5 years 517 520 5 years - 10 years 504 461 10 years - 15 years 121 117 15 years - 20 years 179 161 20 years+ 367 334 Total $1,770 $1,655 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $661 million, $889 million, and $1,465 million, respectively. During the year ended December 31, 2023, there were gross gains of $1 million and gross losses of $37 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $2 million and $29 million, respectively, and gross losses of $46 million and $17 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $496.9 $2.4 $53.6 2022 Debt Securities $470.7 $0.2 $69.3 The amortized cost of available-for-sale debt securities was $548.1 million as of December 31, 2023 and $539.8 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 2.66%, an average duration of approximately 6.02 years, and an average maturity of approximately 7.64 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $175 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $22.5 $0.4 $197.6 $18.8 More than 12 months 403.4 53.2 260.1 50.5 Total $425.9 $53.6 $457.7 $69.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $45.3 $21.2 1 year - 5 years 132.2 159.7 5 years - 10 years 205.7 191.7 10 years - 15 years 39.9 38.0 15 years - 20 years 49.6 42.6 20 years+ 24.2 17.5 Total $496.9 $470.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $28.5 million, $42.1 million, and $57.6 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.1 million and gross losses of $2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.1 million and $2.5 million, respectively, and gross losses of $2.6 million and $0.6 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $788.1 $11.7 $37.4 2022 Debt Securities $725.1 $3.5 $67.5 The amortized cost of available-for-sale debt securities was $813.9 million as of December 31, 2023 and $789.1 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.91%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.16 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $251.3 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $69.8 $0.9 $409.9 $24.6 More than 12 months 356.1 36.5 207.5 42.9 Total $425.9 $37.4 $617.4 $67.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $31.4 $33.6 1 year - 5 years 181.6 159.1 5 years - 10 years 170.0 161.7 10 years - 15 years 70.2 67.1 15 years - 20 years 90.2 83.3 20 years+ 244.7 220.3 Total $788.1 $725.1 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $318.6 million, $362.2 million, and $303.4 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.5 million and gross losses of $20.9 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $1.3 million and $6.8 million, respectively, and gross losses of $23 million and $4.1 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $485.2 $4.5 $42.5 2022 Debt Securities $459.7 $0.7 $63.7 The amortized cost of available-for-sale debt securities was $523.2 million as of December 31, 2023 and $522.7 million as of December 31, 2022. As of December 31, 2023, the available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.44 years, and an average maturity of approximately 10.27 years. The unrealized gains/(losses) recognized during the year ended December 31, 2023 on equity securities still held as of December 31, 2023 were $164.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.1 $4.5 $231.9 $19.2 More than 12 months 239.1 38.0 198.0 44.5 Total $281.2 $42.5 $429.9 $63.7 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $5.3 $6.8 1 year - 5 years 203.4 201.7 5 years - 10 years 128.6 107.1 10 years - 15 years 10.7 11.7 15 years - 20 years 38.8 35.0 20 years+ 98.4 97.4 Total $485.2 $459.7 During the years ended December 31, 2023, 2022, and 2021, proceeds from the dispositions of available-for-sale securities amounted to $314.3 million, $209.4 million, and $513.8 million, respectively. During the year ended December 31, 2023, there were gross gains of $0.6 million and gross losses of $14.2 million related to available-for-sale securities reclassified out of other regulatory liabilities/assets into earnings. During the years ended December 31, 2022 and 2021, there were gross gains of $0.2 million and $9.3 million, respectively, and gross losses of $10.7 million and $4 million, respectively, related to available-for-sale securities reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. |
Variable Interest Entities
Variable Interest Entities | 12 Months Ended |
Dec. 31, 2023 | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Entergy Arkansas [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Entergy Louisiana [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Entergy Mississippi [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Entergy New Orleans [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Entergy Texas [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
System Energy [Member] | |
Variable Interest Entity Disclosure [Text Block] | VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is required to pay advance rent (Entergy Arkansas VIE, Entergy Louisiana Waterford VIE, and System Energy VIE) or special payments (Entergy Louisiana River Bend VIE) to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Texas Restoration Funding, LLC and Entergy Texas Restoration Funding II, LLC, companies wholly-owned and consolidated by Entergy Texas, are VIEs and Entergy Texas is the primary beneficiary. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. Although the principal amount was not due until November 2023, Entergy Texas Restoration Funding made principal payments on the bonds in 2022, after which the bonds were fully repaid. In April 2022, Entergy Texas Restoration Funding II issued senior secured system restoration bonds (securitization bonds) to finance Entergy Texas’s Hurricane Laura, Hurricane Delta, and Winter Storm Uri restoration costs. With the proceeds, the VIEs purchased from Entergy Texas the transition property, which is the right to recover from customers through a system restoration charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the VIEs, including the transition property, and the creditors of the VIEs do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the VIEs except to remit system restoration charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a VIE and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust I was established as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. Entergy Louisiana is the primary beneficiary of the storm trust I because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust I. As of December 31, 2023 and 2022, the primary asset held by the storm trust I was $3 billion and $3.2 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust I’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust I. The holders of the securitization bonds do not have recourse to the assets or revenues of the trust or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.5 million and $31.7 million as of December 31, 2023 and 2022, respectively. See Note 2 to the financial statements for additional discussion of the securitization bonds and the preferred membership interests. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. The storm trust II was established as part of the March 2023 Act 293 securitization of Entergy Louisiana’s Hurricane Ida restoration costs, less Hurricane Ida amounts previously financed in May 2022 in a prior securitization transaction. Entergy Louisiana is the primary beneficiary of the storm trust II because it was created to facilitate the financing of Entergy Louisiana’s storm restoration costs and Entergy Louisiana is entitled to receive a majority of the proceeds received by the storm trust II. As of December 31, 2023, the primary asset held by the storm trust II is the $1.5 billion of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The storm trust II’s investment in affiliate preferred membership interests was purchased with the net bond proceeds of the securitization bonds issued by the LCDA. After the securitization bonds were issued, the LCDA loaned the net bond proceeds to the LURC, and pursuant to Act 293, the LURC contributed the net bond proceeds to the storm trust II. The holders of the securitization bonds do not have recourse to the assets or revenues of the storm trust II or to any Entergy affiliate and the bonds are not reflected in the consolidated balance sheets of Entergy or Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is presented as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with a balance of $14.6 million as of December 31, 2023. See Note 2 to the financial statements herein for additional discussion of the securitization bonds and the preferred membership interests. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments under this arrangement, including interest, of $17.2 million in 2023, $17.2 million in 2022, and $17.2 million in 2021. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Arkansas is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2023, AR Searcy Partnership, LLC recorded assets equal to $134 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $111.2 million. As of December 31, 2022, AR Searcy Partnership, LLC recorded assets equal to $138.3 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $109 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. MS Sunflower Partnership, LLC, is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of MS Sunflower Partnership, LLC and the acquisition of the Sunflower Solar facility. The entity is a VIE because the holders of the membership interests, as a group, lack the characteristics of a controlling financial interest, including substantive kick out rights. Entergy Mississippi is the primary beneficiary of the partnership because, as the managing member, it has the right to direct the operations and receive a majority of the operating income of the partnership. See Note 1 to the financial statements for discussion of the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Mississippi’s investment in MS Sunflower Partnership, LLC. As of December 31, 2023, MS Sunflower Partnership, LLC recorded assets equal to $163.2 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $128.4 million. As of December 31, 2022, MS Sunflower Partnership, LLC recorded assets equal to $154.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $117.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be VIEs. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both. |
Transactions With Affiliates
Transactions With Affiliates | 12 Months Ended |
Dec. 31, 2023 | |
Entergy Arkansas [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Louisiana [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Mississippi [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy New Orleans [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Texas [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
System Energy [Member] | |
Related Party Transactions Disclosure [Text Block] | TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in the Entergy system money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana received preferred membership interest distributions from Entergy Holdings Company through May 2022, at which point Entergy Holdings Company was dissolved. As a result of storm securitizations at Entergy Louisiana in 2022 and 2023, the Entergy Louisiana storm trust I purchased preferred membership interests issued by Entergy Finance Company in May 2022 and the Entergy Louisiana storm trust II purchased preferred membership interests issued by Entergy Finance Company in March 2023. The Entergy Louisiana storm trust I and storm trust II receive annual dividends on their respective preferred membership interests. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Revenue Recognition Revenue Rec
Revenue Recognition Revenue Recognition | 12 Months Ended |
Dec. 31, 2023 | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Entergy Arkansas [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Entergy Louisiana [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Entergy Mississippi [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Entergy New Orleans [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Entergy Texas [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
System Energy [Member] | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred, but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for their own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Other Revenues Entergy’s revenues from its non-utility operations i nclude the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market PPA . In 2022 and 2021, the majority of revenues were from the Palisades nuclear power plant located in Michigan, which was shut down in May 2022 and subsequently sold in June 2022. Almost all of the Palisades nuclear plant output was sold under a 15-year PPA with Consumers Energy, which was executed as part of the acquisition of the plant in 2007 and expired in April 2022. Prices under the original PPA ranged from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA was $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022 at a price of $24.14/MWh. Entergy issued monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortized a liability to revenue over the life of the agreement. The amount amortized each period was based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $5 million in 2022 and $12 million in 2021. See Note 14 to the financial statements for discussion of the sale of the Palisades plant. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accor dingly. Some Entergy subsidiaries in the non-utility operations business have services contracts that have fixed components and terms longer than one year. T he total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. The rate of customer write-offs has historically experienced minimal variation, although general economic conditions, such as the COVID-19 pandemic or other economic hardships, can affect the rate of customer write-offs. Management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. |
Schedule II - Valuation And Qua
Schedule II - Valuation And Qualifying Accounts | 12 Months Ended |
Dec. 31, 2023 | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY CORPORATION AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $30,856 $38,508 $43,459 $25,905 2022 $68,608 $40,307 $78,059 $30,856 2021 $117,794 $57,517 $106,703 $68,608 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Entergy Arkansas [Member] | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY ARKANSAS, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $6,528 $9,428 $8,774 $7,182 2022 $13,072 $14,947 $21,491 $6,528 2021 $18,334 $30,433 $35,695 $13,072 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Entergy Louisiana [Member] | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY LOUISIANA, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $7,595 $13,876 $15,315 $6,156 2022 $29,231 $10,574 $32,210 $7,595 2021 $45,693 $17,219 $33,681 $29,231 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Entergy Mississippi [Member] | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY MISSISSIPPI, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $2,472 $7,275 $6,435 $3,312 2022 $7,209 $3,052 $7,789 $2,472 2021 $19,527 $850 $13,168 $7,209 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Entergy New Orleans [Member] | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $11,909 $3,350 $7,489 $7,770 2022 $13,282 $7,691 $9,064 $11,909 2021 $17,430 $6,850 $10,998 $13,282 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Entergy Texas [Member] | |
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ENTERGY TEXAS, INC. AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2023, 2022, and 2021 (In Thousands) Column A Column B Column C Column D Column E Additions Other Changes Description Balance at Beginning of Period Charged to Income Deductions (2) Balance at End of Period Allowance for doubtful accounts 2023 $2,352 $4,579 $5,447 $1,484 2022 $5,814 $4,042 $7,504 $2,352 2021 $16,810 $2,166 $13,162 $5,814 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off. |
Pay vs Performance Disclosure
Pay vs Performance Disclosure - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Pay vs Performance Disclosure | |||
Net Income (Loss) | $ 2,356,536 | $ 1,103,166 | $ 1,118,492 |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Dec. 31, 2023 | |
Trading Arrangements, by Individual | |
Rule 10b5-1 Arrangement Adopted | false |
Non-Rule 10b5-1 Arrangement Adopted | false |
Rule 10b5-1 Arrangement Terminated | false |
Non-Rule 10b5-1 Arrangement Terminated | false |
Summary Of Significant Accoun_2
Summary Of Significant Accounting Policies (Policy) | 12 Months Ended |
Dec. 31, 2023 | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Partnerships with disproportionate allocation of earnings and losses in relation to an investor's ownership interest [Policy Text Block] | Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Entergy Arkansas [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Partnerships with disproportionate allocation of earnings and losses in relation to an investor's ownership interest [Policy Text Block] | Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Entergy Louisiana [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Entergy Mississippi [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Partnerships with disproportionate allocation of earnings and losses in relation to an investor's ownership interest [Policy Text Block] | Partnerships with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas and Entergy Mississippi, as managing members, each control a tax equity partnership with a third party tax equity investor and consolidate the partnerships for financial reporting purposes. For each respective partnership, the limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between the Registrant Subsidiary and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to the Registrant Subsidiary. Each Registrant Subsidiary has the option to purchase, at a future date specified in their respective partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, each Registrant Subsidiary accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both the Registrant Subsidiary and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between the Registrant Subsidiary and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to the Registrant Subsidiary. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between the Registrant Subsidiary and the tax equity investor. Entergy Arkansas and Entergy Mississippi have determined these differences are primarily due to timing, and both the APSC and the MPSC have approved that, for purposes of ratemaking, each Registrant Subsidiary reflect its interest in its respective partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, each Registrant Subsidiary has recorded a regulatory liability for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Entergy New Orleans [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Entergy Texas [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
System Energy [Member] | |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. |
Revenues And Fuel Costs [Policy Text Block] | Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 Depreciation rates on average depreciable property for Entergy approximated 2.9% in 2023, 2.8% in 2022, and 2.7% in 2021. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $193 million as of December 31, 2023 and $208 million as of December 31, 2022. Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% Non-utility property - at cost (less accumulated depreciation) for Entergy Arkansas is reported net of accumulated depreciation of $0.1 million as of December 31, 2023 and $0.1 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $187.2 million as of December 31, 2023 and $202.2 million as of December 31, 2022. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2023 and $0.5 million as of December 31, 2022. |
Jointly Owned Generating Stations, Policy [Policy Text Block] | Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Outage Costs, Policy [Policy Text Block] | Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. |
Allowance for Funds Used During Construction, Policy [Policy Text Block] | Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. |
Income Tax, Policy [Policy Text Block] | Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 The calculation of diluted earnings per share excluded 1,179,962 options outstanding at December 31, 2023, 931,453 options outstanding at December 31, 2022, and 1,013,320 options outstanding at December 31, 2021 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2023, 1,762,709 shares under a forward sale agreement were not included in the calculation of diluted earnings per share because their effect would have been antidilutive, and at December 31, 2021, 1,158,917 shares under then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. |
Compensation Related Costs, Policy [Policy Text Block] | Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. |
Public Utilities, Policy [Policy Text Block] | Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. |
Securitization Recovery Trust Accounts, Policy [Policy Text Block] | Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. |
Investment, Policy [Policy Text Block] | Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the nuclear plants previously owned by Entergy’s non-utility operations, all of which have been sold as of June 2022, did not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds for these plants were recognized in earnings with no offsetting regulatory liability/asset amount. Unrealized gains/(losses) recorded on the available-for-sale debt securities in the trust funds were recognized in the accumulated other comprehensive income component of shareholders’ equity. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. |
Derivatives, Policy [Policy Text Block] | Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. |
Debt, Policy [Policy Text Block] | Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. |
Taxes Imposed On Revenue Producing Transactions, Policy [Policy Text Block] | Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Pronouncements The accounting standard-setting process is ongoing, and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future results of operations, financial positions, or cash flows. In November 2023 the FASB issued ASU 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures.” The ASU is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. In addition, the ASU requires enhanced interim disclosures, provides new segment disclosure requirements for entities with a single reportable segment, and contains other new disclosure requirements. ASU 2023-07 is effective for Entergy for fiscal years beginning after December 15, 2023, and for interim periods within fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-07 to materially affect its results of operations, financial positions, or cash flows. In December 2023 the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” The ASU is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in the ASU require enhanced income tax disclosures, primarily related to consistent categorization and disaggregation of information in the rate reconciliation and income taxes paid disaggregated by jurisdiction. The ASU also removes certain disclosures that are no longer considered cost beneficial or relevant. ASU 2023-09 is effective for Entergy for fiscal years beginning after December 15, 2024. Entergy does not expect ASU 2023-09 to materially affect its results of operations, financial positions, or cash flows. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. |
Regulatory Income Taxes, Policy [Policy Text Block] | Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. |
Summary Of Significant Accoun_3
Summary Of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for Entergy by functional category, as of December 31, 2023 and 2022, is shown below: 2023 2022 (In Millions) Production Nuclear $7,944 $7,936 Other 7,045 7,256 Transmission 9,927 9,590 Distribution 12,927 12,363 Other 3,173 2,906 Construction work in progress 2,110 1,844 Nuclear fuel 708 582 Property, plant, and equipment - net $43,834 $42,477 |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block] | The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Years Ended December 31, 2023 2022 2021 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share $/share Consolidated net income $2,362,310 $1,097,138 $1,118,719 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Basic shares and earnings per average common share 211.6 $11.14 204.5 $5.40 200.9 $5.57 Average dilutive effect of: Stock options 0.3 (0.01) 0.4 (0.01) 0.4 (0.01) Other equity plans 0.5 (0.03) 0.5 (0.02) 0.6 (0.02) Equity forwards — — 0.1 — — — Diluted shares and earnings per average common share 212.4 $11.10 205.5 $5.37 201.9 $5.54 |
Entergy Arkansas [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Entergy Louisiana [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Entergy Mississippi [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Entergy New Orleans [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Entergy Texas [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
System Energy [Member] | |
Public Utility Property, Plant, and Equipment [Table Text Block] | Net property, plant, and equipment (including property under lease and associated accumulated amortization) for the Registrant Subsidiaries by functional category, as of December 31, 2023 and 2022, is shown below: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,859 $4,153 $— $— $— $1,932 Other 892 3,583 958 386 1,177 — Transmission 2,102 4,283 1,483 143 1,882 32 Distribution 3,395 4,371 2,272 692 2,197 — Other 571 1,156 395 370 311 38 Construction work in progress 341 593 140 25 858 131 Nuclear fuel 214 333 — — — 161 Property, plant, and equipment - net $9,374 $18,472 $5,248 $1,616 $6,425 $2,294 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,858 $4,116 $— $— $— $1,962 Other 916 3,652 988 403 1,244 — Transmission 2,086 4,055 1,435 131 1,846 34 Distribution 2,981 4,827 2,035 625 1,895 — Other 508 1,062 357 357 289 17 Construction work in progress 417 737 170 40 339 103 Nuclear fuel 176 213 — — — 193 Property, plant, and equipment - net $8,942 $18,662 $4,985 $1,556 $5,613 $2,309 |
Schedule Of Depreciation Rates On Average Depreciable Property [Table Text Block] | Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2023 2.7% 2.6% 3.6% 3.3% 4.0% 1.6% 2022 2.7% 2.4% 3.6% 3.2% 3.1% 2.0% 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% |
Schedule of Jointly Owned Utility Plants [Table Text Block] | As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility: Entergy Arkansas - Independence Unit 1 Coal 824 31.50 % $145 $108 Independence Common Facilities Coal 15.75 % $42 $31 White Bluff Units 1 and 2 Coal 1,244 57.00 % $593 $404 Ouachita (b) Common Facilities Gas 66.67 % $173 $159 Union (c) Common Facilities Gas 25.00 % $29 $12 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 514 40.25 % $299 $224 Roy S. Nelson Unit 6 Common Facilities Coal 22.04 % $22 $11 Big Cajun 2 Unit 3 Coal 548 24.15 % $149 $136 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $79 Acadia Common Facilities Gas 50.00 % $22 $3 Union (c) Common Facilities Gas 50.00 % $59 $14 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,666 25.00 % $293 $182 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $30 $10 Entergy Texas - Roy S. Nelson Unit 6 Coal 514 29.75 % $211 $141 Roy S. Nelson Unit 6 Common Facilities Coal 16.30 % $8 $4 Big Cajun 2 Unit 3 Coal 548 17.85 % $112 $101 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $2 Montgomery County Unit 1 Gas 915 92.44 % $745 $54 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,383 90.00 % $5,499 $3,494 Other: Independence Unit 2 Coal 842 14.37 % $79 $59 Independence Common Facilities Coal 7.18 % $21 $15 Roy S. Nelson Unit 6 Coal 514 10.90 % $120 $74 Roy S. Nelson Unit 6 Common Facilities Coal 5.97 % $3 $1 (a) “Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. |
Rate And Regulatory Matters (Ta
Rate And Regulatory Matters (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Regulatory Assets [Table Text Block] | Entergy 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $1,655.5 $1,968.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 1,285.0 1,103.2 Removal costs (Note 9) 1,010.7 1,058.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 536.9 841.3 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 250.9 194.7 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 248.6 160.0 Retired electric and gas meters - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) 153.8 166.8 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Deferred COVID-19 costs - recovered through retail rates as determined by retail regulators (Note 2 - Retail Rate Proceedings ) (b) 118.0 120.9 Unamortized loss on reacquired debt - recovered over term of debt 63.1 68.4 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 143.9 157.4 Entergy Total $5,669.4 $6,036.4 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,826.2 $1,237.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined by retail regulators 138.0 180.2 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 98.0 — Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Vidalia purchased power agreement (Note 8) 82.5 95.4 Deferred tax equity partnership earnings (Note 1) 57.9 43.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Other 149.5 101.9 Entergy Total $3,116.9 $2,324.6 |
Entergy Louisiana [Member] | |
Schedule of Regulatory Assets [Table Text Block] | Entergy Louisiana 2023 2022 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) $412.0 $481.7 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) 408.7 346.3 Removal costs (Note 9) 262.3 418.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators ) 202.6 472.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 123.0 93.9 Retired electric and gas meters - recovered over a 22-year period through July 2041 83.2 88.0 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (a) 47.8 47.8 Unamortized loss on reacquired debt - recovered over term of debt 23.4 25.1 Other 85.9 81.8 Entergy Louisiana Total $1,648.9 $2,056.2 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy Louisiana 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $644.0 $438.9 Securitization financing savings obligation (Note 3) 405.2 327.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 86.4 87.7 Vidalia purchased power agreement (Note 8) 82.5 95.4 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 44.3 43.5 Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) 38.0 — Shorter-term financing interest earnings (Note 2 - Retail Rate Proceedings ) (a) 36.8 — Hurricane Ida insurance proceeds - refunded through rate rider as rates are determined periodically 32.3 — Sale-leaseback and depreciation refunds - returned to customers September 2023 through August 2024 14.1 — Other 24.1 44.8 Entergy Louisiana Total $1,407.7 $1,038.0 |
Deferred Fuel Cost [Table Text Block] | The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. |
Opportunity Sales Proceeding [Table Text Block] | Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33) |
Entergy New Orleans [Member] | |
Schedule of Regulatory Assets [Table Text Block] | Entergy New Orleans 2023 2022 (In Millions) Removal costs (Note 9) $61.1 $56.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 41.4 51.4 Retired electric and gas meters - recovered over a 12-year period through July 2031 (b) 15.5 17.6 Deferred COVID-19 costs - recovered over a five-year period through August 2028 (Note 2 - Retail Rate Proceedings ) (b) 13.0 13.9 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 11.8 9.4 Gas cross-boring costs - recovered through formula rates as rates are redetermined by retail regulators 10.9 9.9 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 3.9 17.2 Unamortized loss on reacquired debt - recovered over term of debt 0.8 1.2 Other 24.0 25.2 Entergy New Orleans Total $182.4 $202.1 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy New Orleans 2023 2022 (In Millions) Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit (Note 3) $60.0 $— Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 20.1 19.5 Sale-leaseback and depreciation refunds - returned to customers over a 10-year period beginning September 2023 (Note 2) 9.8 — Other 0.5 1.2 Entergy New Orleans Total $90.4 $20.7 |
Deferred Fuel Cost [Table Text Block] | The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. |
Opportunity Sales Proceeding [Table Text Block] | Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33) |
Entergy Texas [Member] | |
Schedule of Regulatory Assets [Table Text Block] | Entergy Texas 2023 2022 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Ike and Gustav and Entergy Texas Securitization Bonds - Hurricane Laura, Hurricane Delta, and Winter Storm Uri ) $297.3 $315.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 85.6 100.5 Removal costs (Note 9) 77.5 62.9 Pension & postretirement benefits expense deferral - recovered through retail rates (Note 2 - Retail Rate Proceedings and Note 11 - Entergy Texas Reserve ) 32.7 30.6 Rate case depreciation relate back deferral - will be recovered over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 27.6 — Advanced metering system (AMS) surcharge for residential customers - recovered through December 2029 20.2 — Retired electric meters - recovered through retail rates (Note 2 - Retail Rate Proceedings ) 18.8 21.4 Neches and Sabine costs - recovered over a 10-year period through September 2028 11.6 14.0 Deferred COVID-19 costs - recovered through retail rates (Note 2 - Retail Rate Proceedings ) (b) 8.4 10.4 Unamortized loss on reacquired debt - recovered over term of debt 8.3 9.1 Other 8.6 14.4 Entergy Texas Total $596.6 $578.7 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy Texas 2023 2022 (In Millions) Retail rate rider over-recovery - return to customers to be determined $23.8 $10.9 Rate case settlement relate back - will be amortized over a six-month period beginning January 2024 (Note 2 - Retail Rate Proceedings ) 10.3 — Retail refunds - return to customers to be determined 6.2 25.5 Securitization over-recovery - return to customers to be determined (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) 0.3 8.8 Other 2.4 — Entergy Texas Total $43.0 $45.2 |
Deferred Fuel Cost [Table Text Block] | The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. |
Opportunity Sales Proceeding [Table Text Block] | Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33) |
System Energy [Member] | |
Schedule of Regulatory Assets [Table Text Block] | System Energy 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear unit (Note 9) (b) $222.0 $186.1 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) 121.6 133.9 Removal costs - recovered through depreciation rates (Note 9) 102.1 94.4 Unamortized loss on reacquired debt - recovered over term of debt 0.7 0.7 System Energy Total $446.4 $415.1 |
Schedule of Regulatory Liabilities [Table Text Block] | System Energy 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $560.6 $370.8 Complaints against System Energy - potential future refunds (Note 2) (b) 177.9 249.8 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 System Energy Total $782.9 $665.0 |
Entergy Mississippi [Member] | |
Schedule of Regulatory Assets [Table Text Block] | Entergy Mississippi 2023 2022 (In Millions) Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined annually $192.8 $111.1 Removal Costs (Note 9) 188.0 159.4 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 127.6 148.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost) 32.0 24.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 10.9 15.7 Unamortized loss on reacquired debt - recovered over term of debt 10.0 10.9 Asset retirement obligation - recovery dependent upon timing of shutdown of non-nuclear power plants (Note 9) (a) 6.8 6.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 18.2 Other 11.0 24.8 Entergy Mississippi Total $579.1 $519.5 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy Mississippi 2023 2022 (In Millions) Deferred tax equity partnership earnings (Note 1) $30.5 $21.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 2.4 58.2 Other 0.8 0.3 Entergy Mississippi Total $33.7 $79.9 |
Deferred Fuel Cost [Table Text Block] | The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. |
Opportunity Sales Proceeding [Table Text Block] | Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33) |
Entergy Arkansas [Member] | |
Schedule of Regulatory Assets [Table Text Block] | Entergy Arkansas 2023 2022 (In Millions) Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or shutdown of non-nuclear power plants (Note 9) (a) $639.1 $562.7 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 536.6 597.6 Removal costs (Note 9) 319.7 267.1 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered through October 2034 (Note 11 - Qualified Pension Settlement Cost ) 84.1 67.1 Deferred COVID-19 costs - recovered over a 10-year period through December 2033 39.0 39.0 Retired electric meters - recovered over 15-year period through March 2034 36.3 39.8 Storm damage costs - recovered through retail rates 33.1 35.9 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 24.9 26.4 Unamortized loss on reacquired debt - recovered over term of debt 19.9 21.4 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (b) 3.8 5.6 Other 17.1 15.9 Entergy Arkansas Total $1,885.4 $1,810.3 |
Schedule of Regulatory Liabilities [Table Text Block] | Entergy Arkansas 2023 2022 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $621.6 $428.2 Refund from System Energy settlement with the APSC - return to customers to be determined (Note 2) 93.0 — Deferred tax equity partnership earnings (Note 1) 27.4 22.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 10.6 3.9 Internal restructuring guaranteed customer credits - returned to customers over a six-year period through December 2024 6.6 13.2 Other — 8.1 Entergy Arkansas Total $759.2 $475.8 |
Deferred Fuel Cost [Table Text Block] | The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2023 2022 (In Millions) Entergy Arkansas (a) ($88.3) $208.6 Entergy Louisiana (b) $192.9 $327.3 Entergy Mississippi ($130.6) $143.2 Entergy New Orleans (b) $10.2 $14.2 Entergy Texas $139.0 $258.1 (a) Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. In 2023, Entergy Arkansas recorded a write-off of its regulatory asset for deferred fuel of $68.9 million as a result of Entergy Arkansas’s approved motion to forgo recovery of identified costs resulting from the 2013 ANO stator incident . See Note 8 to the financial statements for further discussion of the 2013 ANO stator incident. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. |
Opportunity Sales Proceeding [Table Text Block] | Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33) |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for Entergy for 2023, 2022, and 2021 consist of the following: 2023 2022 2021 (In Thousands) Current: Federal $60,639 $32,387 ($5,003) State 23,014 (3,091) (8,995) Total 83,653 29,296 (13,998) Deferred and non-current - net (768,941) (67,520) 205,891 Investment tax credits - net (5,247) (754) (519) Income taxes ($690,535) ($38,978) $191,374 |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 2022 2021 (In Thousands) Net income attributable to Entergy Corporation $2,356,536 $1,103,166 $1,118,492 Preferred dividend requirements of subsidiaries and noncontrolling interests 5,774 (6,028) 227 Consolidated net income 2,362,310 1,097,138 1,118,719 Income taxes (690,535) (38,978) 191,374 Income before income taxes $1,671,775 $1,058,160 $1,310,093 Income taxes computed at statutory rate (21%) $351,073 $222,214 $275,120 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 70,144 61,368 79,273 Regulatory differences - utility plant items (27,901) (32,143) (57,556) Equity component of AFUDC (20,172) (14,156) (14,799) Amortization of investment tax credits (7,978) (7,740) (7,695) Flow-through / permanent differences (1,374) 1,011 (5,585) Amortization of excess ADIT (a) 9,102 (34,899) (66,478) Arkansas and Louisiana rate changes (b) — — (27,108) IRS audit resolution (c) (842,769) — — Reversal of regulatory liability for Hurricane Isaac (d) (105,649) — — Entergy Louisiana securitization (e) (129,034) (282,620) — System Energy sale-leaseback order (f) — 12,662 — Provision for uncertain tax positions 18,884 34,423 16,533 Valuation allowance (8,697) (2,754) (2,600) Other - net 3,836 3,656 2,269 Total income taxes as reported ($690,535) ($38,978) $191,374 Effective Income Tax Rate (41.3 %) (3.7 %) 14.6 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2023, 2022, and 2021 and the tax legislation enactment in 2017. (b) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See “ Other Tax Matters – Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (f) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,192,156) ($5,270,010) Regulatory assets (989,405) (937,554) Nuclear decommissioning trusts/receivables (467,267) (318,570) Pension, net regulatory asset (363,829) (336,496) Combined unitary state taxes (8,783) (10,335) Power purchase agreements (75,612) (3,993) Accumulated storm damage provision (2,474) (35,213) Deferred fuel (69,436) (181,222) Other (251,107) (333,421) Total (8,420,069) (7,426,814) Deferred tax assets: Nuclear and other decommissioning liabilities 147,011 173,201 Regulatory liabilities 1,247,530 1,108,075 Pension and other post-employment benefits 116,222 141,399 Compensation 81,226 76,317 Accumulated deferred investment tax credit 55,928 57,501 Provision for allowances and contingencies 149,479 97,545 Unbilled/deferred revenues 2,418 21,905 Net operating loss carryforwards 2,857,908 2,065,149 Capital losses and miscellaneous tax credits 107,009 28,876 Valuation allowance (372,119) (372,017) Other 220,055 245,236 Total 4,612,667 3,643,187 Non-current accrued taxes (including unrecognized tax benefits) (422,213) (951,110) Accumulated deferred income taxes and taxes accrued ($4,229,615) ($4,734,737) |
Summary of Tax Credit Carryforwards [Table Text Block] | Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $4.2 billion 2028-2037 Federal net operating losses - 1/1/2018 forward $13.8 billion N/A State net operating losses $3.9 billion 2028-2042 State net operating losses with no expiration $11.1 billion N/A Other federal and state carryforwards $523.6 million 2024-2037 Miscellaneous federal and state credits $124.9 million 2024-2043 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2023 2022 2021 (In Thousands) Gross balance at January 1 $6,393,599 $5,759,968 $5,699,339 Additions based on tax positions related to the current year 332,884 792,134 101,623 Additions for tax positions of prior years 194,894 37,259 33,419 Reductions for tax positions of prior years (a) (1,300,381) (195,762) (74,413) Settlements (a) (3,181,086) — — Gross balance at December 31 2,439,910 6,393,599 5,759,968 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (2,160,484) (5,566,212) (4,987,799) Cash paid to taxing authorities — (82,000) (60,000) Unrecognized tax benefits net of unused tax attributes and payments (b) $279,426 $745,387 $712,169 (a) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. (b) Potential tax liability above what is payable on tax returns. |
Entergy Arkansas [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
Entergy Louisiana [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
Entergy Mississippi [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
Entergy New Orleans [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
Entergy Texas [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
System Energy [Member] | |
Tax Cuts and Jobs Act [Table Text Block] | The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows: 2023 2022 (In Millions) Entergy Arkansas $392 $435 Entergy Louisiana $194 $338 Entergy Mississippi $189 $202 Entergy New Orleans $36 $40 Entergy Texas $115 $133 System Energy $107 $111 Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | Income taxes for the Registrant Subsidiaries for 2023, 2022, and 2021 consist of the following: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $33,100 ($142,253) $20,328 ($99,343) $2,851 $337 State (4,201) (6,397) 4,142 (5,854) 3,719 (1,570) Total 28,899 (148,650) 24,470 (105,197) 6,570 (1,233) Deferred and non-current - net (126,878) (52,451) 30,690 (84,744) 57,066 31,005 Investment tax credits - net (1,231) (4,680) (796) (32) (764) 2,260 Income taxes ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal $8,015 ($79,079) $9,242 $1,074 $37,471 ($11,720) State (1,066) (1,773) (6,486) 6,221 2,260 581 Total 6,949 (80,852) 2,756 7,295 39,731 (11,139) Deferred and non-current - net 74,802 (77,223) 48,443 16,814 11,520 (83,369) Investment tax credits - net (855) (4,778) 3,665 168 (630) 1,680 Income taxes $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credits - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) |
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2023, 2022, and 2021 are: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $396,850 $1,273,370 $181,969 $228,938 $291,273 $108,772 Income taxes (99,210) (205,781) 54,364 (189,973) 62,872 32,032 Income before income taxes $297,640 $1,067,589 $236,333 $38,965 $354,145 $140,804 Income taxes computed at statutory rate (21%) $62,504 $224,194 $49,630 $8,183 $74,370 $29,569 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 13,291 51,899 11,133 1,907 2,574 5,798 Regulatory differences - utility plant items (8,812) (5,535) (5,290) (1,353) (6,394) (517) Equity component of AFUDC (4,093) (6,754) (1,796) (309) (5,920) (1,301) Amortization of investment tax credits (1,201) (4,625) (223) (25) (748) (1,155) Flow-through / permanent differences 1,105 126 3,534 (1,913) 1,493 (191) IRS audit resolution (a) (159,588) (179,111) (3,291) (198,424) (3,112) (1,575) Amortization of excess ADIT (b) (6,095) 14,032 — 1,147 17 — Entergy Louisiana securitization (c) — (133,443) — — — — Reversal of regulatory liability for Hurricane Isaac (d) — (105,649) — — — — Non-taxable dividend income — (62,116) — — — — Provision for uncertain tax positions 2,600 (400) 300 600 211 1,200 Other - net 1,079 1,601 367 214 381 204 Total income taxes as reported ($99,210) ($205,781) $54,364 ($189,973) $62,872 $32,032 Effective Income Tax Rate (33.3%) (19.3%) 23.0% (487.5%) 17.8% 22.7% 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $292,887 $855,870 $176,267 $64,101 $303,327 ($276,593) Income taxes 80,896 (162,853) 54,864 24,277 50,621 (92,828) Income before income taxes $373,783 $693,017 $231,131 $88,378 $353,948 ($369,421) Income taxes computed at statutory rate (21%) $78,494 $145,534 $48,538 $18,559 $74,329 ($77,578) Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 17,981 44,244 9,659 6,733 2,175 (16,727) Regulatory differences - utility plant items (12,466) (6,347) (7,726) (1,908) (3,010) (686) Equity component of AFUDC (3,437) (5,513) (1,286) (174) (2,841) (905) Amortization of investment tax credits (1,201) (4,720) (223) 175 (614) (1,155) Flow-through / permanent differences 106 3,467 4,837 230 765 (641) Amortization of excess ADIT (b) — (13,164) — (752) (20,983) — System Energy sale-leaseback order (e) — — — — — 12,662 Entergy Louisiana securitization (c) — (289,609) — — — — Non-taxable dividend income — (38,735) — — — — Provision for uncertain tax positions 1,600 400 700 1,200 420 (8,000) Valuation allowance (1,258) — — — — — Other - net 1,077 1,590 365 214 380 202 Total income taxes as reported $80,896 ($162,853) $54,864 $24,277 $50,621 ($92,828) Effective Income Tax Rate 21.6% (23.5%) 23.7% 27.5% 14.3% 25.1% 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Income before income taxes $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Income taxes computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (b) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana rate changes (f) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1% 15.5% 21.4% 15.7% 10.0% (1.9%) (a) See “ Income Tax Audits - 2016-2018 IRS Audit ” below for discussion of the resolution of the 2016-2018 IRS audit in 2023. (b) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess ADIT in 2023, 2022, 2021 and the tax legislation enactment in 2017. (c) See “ Other Tax Matters - Act 293 Securitizations ” below for discussion of the Entergy Louisiana May 2022 and March 2023 storm cost securitizations. (d) See Note 2 to the financial statements for discussion of Entergy Louisiana’s reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the Tax Cuts and Jobs Act. (e) See Note 2 to the financial statements for discussion of the December 2022 FERC order related to the Grand Gulf sale-leaseback renewal complaint. (f) See “ Other Tax Matters - Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. |
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,421,272) ($2,639,079) ($810,120) ($272,187) ($671,072) ($450,559) Regulatory assets (241,427) (500,395) (41,519) (23,618) (104,562) (76,522) Nuclear decommissioning trusts/receivables (154,106) (173,402) — — — (139,858) Pension, net regulatory asset (96,853) (82,305) (24,342) (9,216) (17,522) (18,895) Deferred fuel — (17,065) (21,137) (1,563) (29,194) (37) Accumulated storm damage provision — — — — (1,387) — Power purchase agreements 15,993 (112,292) 1,140 (12,516) (4,551) — Other (21,187) (126,952) (6,844) (4,270) (3,301) (9,051) Total (1,918,852) (3,651,490) (902,822) (323,370) (831,589) (694,922) Deferred tax assets: Regulatory liabilities 296,278 575,459 54,586 42,921 41,137 240,310 Nuclear and other decommissioning liabilities 118,301 9,055 — — 97 19,259 Pension and other post-employment benefits (28,868) 46,837 (10,064) (19,354) (21,977) (2,641) Accumulated deferred investment tax credit 6,761 27,902 3,446 4,431 1,672 11,717 Provision for allowances and contingencies 23,956 70,297 10,072 25,846 8,659 225 Unbilled/deferred revenues 5,962 (20,375) 6,194 1,045 8,365 — Compensation 4,054 6,078 3,649 1,268 2,181 406 Net operating loss carryforwards 94,321 459,553 8,375 26,227 61 35,089 Capital losses and miscellaneous tax credits 7,137 13,073 7,613 15,684 1,655 13,211 Other 17,072 52,438 1,556 (235) 1,740 — Total 544,974 1,240,317 85,427 97,833 43,590 317,576 Non-current accrued taxes (including unrecognized tax benefits) (63,175) 19,731 (4,349) 29,922 (26,906) (28,398) Accumulated deferred income taxes and taxes accrued ($1,437,053) ($2,391,442) ($821,744) ($195,615) ($814,905) ($405,744) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,181,456) ($2,513,138) ($691,675) ($115,841) ($614,134) ($448,010) Regulatory assets (244,624) (457,102) (44,358) (24,738) (95,717) (68,742) Nuclear decommissioning trusts/receivables (107,858) (118,172) — — — (92,527) Pension, net regulatory asset (93,139) (82,891) (22,256) (9,604) (18,111) (17,889) Deferred fuel (35,205) (49,792) (37,333) (2,560) (54,204) (128) Accumulated storm damage provision — (31,337) — — (3,876) — Power purchase agreements (8,296) (11,181) — (9,372) (22,014) — Other (76,813) (126,350) (26,752) (21,977) (4,126) (14,364) Total (1,747,391) (3,389,963) (822,374) (184,092) (812,182) (641,660) Deferred tax assets: Regulatory liabilities 236,318 508,594 54,454 27,438 47,248 237,452 Nuclear and other decommissioning liabilities 139,499 12,883 1 — 97 18,940 Pension and other post-employment benefits (28,463) 52,414 (9,196) (18,114) (20,867) (2,481) Accumulated deferred investment tax credit 7,171 29,271 3,641 4,438 1,829 11,151 Provision for allowances and contingencies 26,432 15,741 10,300 26,671 7,755 — Unbilled/deferred revenues 6,211 (2,405) 5,826 4,090 7,572 — Compensation 3,361 5,207 2,316 1,107 1,712 308 Net operating loss carryforwards 10,491 307,175 10,140 12,146 27,620 20,639 Capital losses and miscellaneous tax credits 719 2,774 5,152 11,006 3,728 8,261 Other 24,969 41,310 6,849 11,105 729 — Total 426,708 972,964 89,483 79,887 77,423 294,270 Non-current accrued taxes (including unrecognized tax benefits) (177,551) 42,121 (47,139) (281,054) (9,468) (28,680) Accumulated deferred income taxes and taxes accrued ($1,498,234) ($2,374,878) ($780,030) ($385,259) ($744,227) ($376,070) |
Summary of Tax Credit Carryforwards [Table Text Block] | The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— million $0.8 billion $— million $0.1 billion $— million $— million Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $0.5 billion $2.8 billion $10.8 million $17.7 million $1.8 billion $0.1 billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $0.4 billion $5.7 billion $0.1 billion $0.2 billion $1 million $0.2 billion Year(s) of expiration 2028-2032 N/A 2040-2042 N/A 2028 N/A Misc. federal credits $10 million $16.9 million $3.9 million $16.1 million $0.8 million $4.8 million Year(s) of expiration 2038-2043 2035-2043 2038-2043 2037-2043 2039-2043 2029-2043 State credits $— million $— million $8 million $— million $1.6 million $19 million Year(s) of expiration N/A N/A 2024-2026 N/A 2027-2033 2024-2027 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2023 $1,452,819 $1,350,836 $547,548 $638,726 $389,366 $23,702 Additions based on tax positions related to the current year (a) 2,249 332,320 209 78 196 752 Additions for tax positions of prior years — — — — 94,793 — Reductions for tax positions of prior years (b) (148,558) (458,072) (16,853) (191,336) (67,156) (9,532) Settlements (b) (1,237,313) (361,041) (525,251) (428,137) (1,994) (621) Gross balance at December 31, 2023 69,197 864,043 5,653 19,331 415,205 14,301 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (34,683) (735,612) (3,778) (11,721) (381,561) (14,301) Unrecognized tax benefits net of unused tax attributes $34,514 $128,431 $1,875 $7,610 $33,644 $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2022 $1,408,494 $604,628 $549,569 $639,497 $552,295 $23,356 Additions based on tax positions related to the current year (a) 40,502 750,320 185 72 173 690 Additions for tax positions of prior years 6,233 10,262 1,122 393 801 761 Reductions for tax positions of prior years (2,410) (14,374) (3,328) (1,236) (163,903) (1,105) Gross balance at December 31, 2022 1,452,819 1,350,836 547,548 638,726 389,366 23,702 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,277,414) (1,328,916) (504,940) (455,928) (377,054) (23,702) Unrecognized tax benefits net of unused tax attributes $175,405 $21,920 $42,608 $182,798 $12,312 $— 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes $415,851 $— $160,841 $154,598 $11,601 $14,780 (a) The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations as discussed in “ Other Tax Matters - Act 293 Securitizations ” below. (b) Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “ Income Tax Audits - 2016-2018 IRS Audit ” below. |
Summary of Income Tax Contingencies [Table Text Block] | The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $57.2 $377.9 $262.1 Entergy Louisiana $862.5 $720.8 $66.3 Entergy Mississippi $1.0 $151.2 $51.7 Entergy New Orleans $18.2 $310.7 $228.6 Entergy Texas $2.9 $3.3 $2.6 System Energy $3.1 $2.5 $1.7 |
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits [Table Text Block] | Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows: December 31, 2023 2022 2021 (In Millions) Entergy Arkansas $7.8 $4.3 $2.7 Entergy Louisiana $1.5 $4.1 $3.7 Entergy Mississippi $2.1 $3.1 $2.4 Entergy New Orleans $0.6 $6.4 $5.2 Entergy Texas $— $1.1 $1.1 System Energy $1.9 $1.9 $12.1 |
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits [Table Text Block] | Interest (net-of-tax) was recorded as follows: 2023 2022 2021 (In Millions) Entergy Arkansas $3.5 $1.6 $0.4 Entergy Louisiana ($2.6) $0.4 $0.3 Entergy Mississippi ($1.0) $0.7 $0.5 Entergy New Orleans ($5.8) $1.2 $1.3 Entergy Texas ($1.1) $— $0.2 System Energy $— ($10.2) $0.2 |
Revolving Credit Facilities, _2
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Summary Of Borrowings Outstanding And Capacity Available Under Facility [Table Text Block] | ollowing is a summary of the amounts outstanding and capacity available under the credit facility as of December 31, 2023: Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $— $3 $3,497 |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel [Table Text Block] | To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. |
Long Term Notes Payable [Table Text Block] | The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million |
Entergy Arkansas [Member] | |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel [Table Text Block] | To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. |
Long Term Notes Payable [Table Text Block] | The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million |
Entergy Louisiana [Member] | |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel [Table Text Block] | To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. |
Long Term Notes Payable [Table Text Block] | The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million |
Entergy Mississippi [Member] | |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Entergy New Orleans [Member] | |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Entergy Texas [Member] | |
Schedule of Line of Credit Facilities [Table Text Block] | Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn Letters of Credit Outstanding as of December 31, 2023 Entergy Arkansas April 2024 $25 million (b) 7.29% — — Entergy Arkansas June 2028 $150 million (c) 6.58% — — Entergy Louisiana June 2028 $350 million (c) 6.71% — — Entergy Mississippi July 2025 $150 million 6.58% — — Entergy New Orleans June 2024 $25 million (c) 7.08% — — Entergy Texas June 2028 $150 million (c) 6.71% — $1.1 million (a) The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Uncommitted standby letter of credit facilities as a means to post collateral to support obligations to MISO [Table Text Block] | In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $5.8 million Entergy Louisiana $125 million 0.78% $17.1 million Entergy Mississippi $65 million 0.78% $20 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $76.5 million (a) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
System Energy [Member] | |
Schedule of Short-Term Debt [Table Text Block] | The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $145 Entergy Louisiana $450 $156 Entergy Mississippi $200 $74 Entergy New Orleans $150 $22 Entergy Texas $200 $— System Energy $200 $12 |
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel [Table Text Block] | To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2023: Company Expiration Date Amount of Facility Weighted-Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2023 (Dollars in Millions) Entergy Arkansas VIE June 2025 $80 6.10% $70.2 Entergy Louisiana River Bend VIE June 2025 $105 6.17% $46.6 Entergy Louisiana Waterford VIE June 2025 $105 6.07% $29.5 System Energy VIE June 2025 $120 5.91% $21.5 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. |
Long Term Notes Payable [Table Text Block] | The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of December 31, 2023 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 5.94% Series J due September 2026 $70 million System Energy VIE 2.05% Series K due September 2027 $90 million |
Long - Term Debt (Tables)
Long - Term Debt (Tables) | 1 Months Ended | 12 Months Ended |
Apr. 30, 2022 | Dec. 31, 2023 | |
Schedule of Maturities of Long-Term Debt [Table Text Block] | Long-term debt for Entergy as of December 31, 2023 and 2022 consisted of: Type of Debt and Maturity Weighted-Average Interest Rate December 31, 2023 Interest Rate Ranges at December 31, Outstanding at 2023 2022 2023 2022 (In Thousands) Mortgage Bonds 2023-2027 3.05% 0.95% - 5.40% 0.62% - 5.59% $4,668,000 $6,808,000 2028-2032 2.88% 1.60%- 6.00% 1.60% - 4.19% 3,590,000 3,265,000 2033-2041 4.12% 2.55% - 5.30% 2.55% - 4.52% 3,122,000 2,097,000 2044-2066 4.22% 2.65% - 5.80% 2.65% - 5.50% 8,355,000 8,005,000 Governmental Bonds (a) 2023-2044 2.43% 2.0% - 2.5% 2.0% - 2.5% 282,375 282,375 Securitization Bonds 2023-2036 3.61% 2.67% - 3.697% 2.67% - 3.697% 267,003 297,363 Variable Interest Entities Notes Payable (Note 4) 2023-2027 2.85% 1.84% - 5.94% 1.84% - 3.22% 320,000 310,000 Entergy Corporation Notes due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% 1.9% 650,000 650,000 due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% 2.40% 650,000 650,000 due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a — 2.5% — 70,000 Entergy New Orleans Unsecured Term Loan due June 2024 n/a 6.25% — 85,000 — Entergy Mississippi Unsecured Term Loan due December 2023 n/a — 4.082% — 150,000 System Energy Term Loan due November 2023 (b) n/a — 3.721% — 50,000 5 Year Credit Facility (Note 4) n/a — 2.97% — 150,000 Entergy Louisiana Credit Facility (Note 4) n/a — 7.75% — 50,000 Vermont Yankee Credit Facility (Note 4) n/a 6.61% 3.19% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 6.10% 2.62% 70,200 — Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 6.17% 2.17% 46,600 13,100 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 6.07% 2.74% 29,500 60,800 System Energy VIE Credit Facility (Note 4) n/a 5.91% 2.77% 21,500 72,600 Long-term DOE Obligation (c) — — — 205,151 195,044 Grand Gulf Sale-Leaseback Obligation n/a — — 34,260 34,297 Unamortized Premium and Discount - Net (11,638) 960 Unamortized Debt Issuance Costs (171,475) (173,464) Other 5,420 5,474 Total Long-Term Debt 25,107,896 25,932,549 Less Amount Due Within One Year 2,099,057 2,309,037 Long-Term Debt Excluding Amount Due Within One Year $23,008,839 $23,623,512 Fair Value of Long-Term Debt $22,489,174 $22,573,837 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) The debt is secured by a series of collateral mortgage bonds. (c) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Amount (In Thousands) 2024 $2,100,275 2025 $1,546,940 2026 $2,375,720 2027 $916,965 2028 $2,195,627 | |
Entergy Arkansas [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.05% Series due June 2023 $— $250,000 3.70% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 5.15% Series due January 2033 425,000 — 5.30% Series due September 2033 300,000 — 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 550,000 550,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 400,000 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 4,335,000 3,860,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.17% Series M due December 2023 — 40,000 1.84% Series N due July 2026 90,000 90,000 Credit Facility due June 2025, weighted-average rate 6.10% 70,200 — Total variable interest entity notes payable and credit facility 160,200 130,000 Other: Long-term DOE Obligation (b) 205,151 195,044 Unamortized Premium and Discount – Net 7,508 12,513 Unamortized Debt Issuance Costs (36,711) (33,009) Other 1,932 1,952 Total Long-Term Debt 4,673,080 4,166,500 Less Amount Due Within One Year 375,000 290,000 Long-Term Debt Excluding Amount Due Within One Year $4,298,080 $3,876,500 Fair Value of Long-Term Debt $4,166,941 $3,538,930 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
Entergy Louisiana [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.05% Series due September 2023 $— $325,000 0.62% Series due November 2023 — 665,000 5.59% Series due October 2024 — 300,000 0.95% Series due October 2024 1,000,000 1,000,000 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 500,000 4.00% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 500,000 5% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.75% Series due September 2052 500,000 500,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 9,065,000 10,355,000 Governmental Bonds (a): 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 16,200 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 182,480 Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.22% Series I due December 2023 — 20,000 5.94% Series J due September 2026 70,000 — 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2025, weighted-average rate 6.17% 46,600 13,100 Credit Facility due June 2025, weighted-average rate 6.07% 29,500 60,800 Total variable interest entity notes payable and credit facilities 216,100 163,900 Other: Credit Facility due June 2027, weighted-average rate 7.75% — 50,000 Unamortized Premium and Discount - Net (6,478) (8,482) Unamortized Debt Issuance Costs (56,101) (63,698) Other 3,488 3,522 Total Long-Term Debt 9,420,689 10,698,922 Less Amount Due Within One Year 1,400,000 1,010,000 Long-Term Debt Excluding Amount Due Within One Year $8,020,689 $9,688,922 Fair Value of Long-Term Debt $8,414,512 $9,444,665 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
Entergy Mississippi [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $— $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 5.0% Series due September 2033 300,000 — 2.55% Series due December 2033 200,000 200,000 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 370,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,245,000 2,195,000 Other: Unsecured Term Loan due December 2023, weighted-average rate 4.082% — 150,000 Unamortized Premium and Discount – Net 5,546 5,803 Unamortized Debt Issuance Costs (21,036) (19,707) Total Long-Term Debt 2,229,510 2,331,096 Less Amount Due Within One Year 100,000 400,000 Long-Term Debt Excluding Amount Due Within One Year $2,129,510 $1,931,096 Fair Value of Long-Term Debt $1,969,334 $1,987,154 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
Entergy New Orleans [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.90% Series due July 2023 $— $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 90,000 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 70,000 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 585,000 685,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 6,245 18,770 Total securitization bonds 6,245 18,770 Other: 2.5% Unsecured Term Loan due May 2023 — 70,000 6.25% Unsecured Term Loan due June 2024 85,000 — Payable to associated company due November 2035 8,279 9,585 Unamortized Premium and Discount – Net (6) (25) Unamortized Debt Issuance Costs (7,068) (7,698) Total Long-Term Debt 677,450 775,632 Less Amount Due Within One Year 86,275 171,306 Long-Term Debt Excluding Amount Due Within One Year $591,175 $604,326 Fair Value of Long-Term Debt $602,716 $707,872 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
Entergy Texas [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) Entergy Texas Mortgage Bonds: 1.50% Series due September 2026 $130,000 $130,000 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 5.00% Series due September 2052 325,000 325,000 5.80% Series due September 2053 350,000 — Total mortgage bonds 2,980,000 2,630,000 Securitization Bonds: 3.051% Series Senior Secured, Series A Tranche A-1 due December 2028 69,908 87,743 3.697% Series Senior Secured, Series A Tranche A-2 due December 2036 190,850 190,850 Total securitization bonds 260,758 278,593 Other: Unamortized Premium and Discount - Net 10,199 11,528 Unamortized Debt Issuance Costs (25,865) (24,208) Total Long-Term Debt 3,225,092 2,895,913 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $3,225,092 $2,895,913 Fair Value of Long-Term Debt $2,936,130 $2,485,705 | |
Schedule of Senior Secured Transition Bonds [Table Text Block] | Amount (In Thousands) Senior Secured System Restoration Bonds: Tranche A-1 (3.051%) due December 2028 $100,000 Tranche A-2 (3.697%) due December 2036 190,850 Total senior secured system restoration bonds $290,850 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
System Energy [Member] | ||
Schedule of Maturities of Long-Term Debt [Table Text Block] | 2023 2022 (In Thousands) System Energy Mortgage Bonds: 4.10% Series due April 2023 $— $250,000 2.14% Series due December 2025 200,000 200,000 6.00% Series due April 2028 325,000 — Total mortgage bonds 525,000 450,000 Governmental Bonds (a): 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 83,695 Total governmental bonds 83,695 83,695 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2025, weighted-average rate 5.91% 21,500 72,600 Total variable interest entity notes payable and credit facility 111,500 162,600 Other: Term Loan due November 2023, weighted-average rate 3.721% (c) — 50,000 Grand Gulf Sale-Leaseback Obligation 34,260 34,297 Unamortized Premium and Discount – Net (10,451) (50) Unamortized Debt Issuance Costs (5,545) (2,637) Total Long-Term Debt 738,459 777,905 Less Amount Due Within One Year 57 300,037 Long-Term Debt Excluding Amount Due Within One Year $738,402 $477,868 Fair Value of Long-Term Debt $696,168 $702,473 | |
Annual Long Term Debt Maturities For Debt [Table Text Block] | The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2023, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2024 $375,000 $1,400,000 $100,000 $86,275 $— $— 2025 $70,200 $376,100 $— $79,140 $— $221,500 2026 $690,000 $720,000 $— $85,720 $130,000 $— 2027 $— $520,000 $150,000 $6,965 $150,000 $90,000 2028 $350,000 $425,000 $375,000 $719 $69,908 $325,000 | |
Present Value Of Future Minimum Lease Payments Sale Leaseback Transactions Text Block [Table Text Block] | As of December 31, 2023, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2024 $17,188 2025 17,188 2026 17,188 2027 17,188 2028 17,188 Years thereafter 137,500 Total 223,440 Less: Amount representing interest 189,180 Present value of net minimum lease payments $34,260 |
Preferred Equity (Tables)
Preferred Equity (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule Of Preferred Equity [Table Text Block] | The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interests for Entergy Corporation subsidiaries as of December 31, 2023 and 2022 are presented below. Shares/Units Shares/Units 2023 2022 2023 2022 2023 2022 (Dollars in Thousands) Preferred stock or preferred membership interests without sinking fund presented between liabilities and equity: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Finance Holding, Inc. 8.75% (d) 250,000 250,000 250,000 250,000 24,249 24,249 Total preferred stock or preferred membership interests without sinking fund presented between liabilities and equity 450,000 450,000 450,000 450,000 219,410 219,410 Preferred stock without sinking fund and noncontrolling interests presented as equity: Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (e) 150,000 150,000 — — — — Entergy Arkansas Noncontrolling Interest — — — — 21,599 27,825 Entergy Louisiana Noncontrolling Interests — — — — 45,107 31,735 Entergy Mississippi Noncontrolling Interest — — — — 18,753 3,347 Total preferred stock without sinking fund and noncontrolling interests presented as equity 1,550,000 1,550,000 1,400,000 1,400,000 120,459 97,907 Total subsidiaries’ preferred stock or preferred membership interests without sinking fund and noncontrolling interests 2,000,000 2,000,000 1,850,000 1,850,000 $339,869 $317,317 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2023. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. (e) Currently, all shares are held by Entergy Corporation. |
Entergy Texas [Member] | |
Schedule Of Preferred Equity [Table Text Block] | The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2023 and 2022 are presented below. Shares Call Price per 2023 2022 2023 2022 2023 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 150,000 3,750 3,750 $25.50 Total without sinking fund 1,550,000 1,550,000 $38,750 $38,750 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2023. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. |
Entergy Arkansas [Member] | |
Schedule of Noncontrolling Interest [Table Text Block] | The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $21,599 $27,825 Total Noncontrolling Interest $21,599 $27,825 (a) AR Searcy Partnership, LLC is a tax equity partnership between Entergy Arkansas and a tax equity investor which was formed to acquire and own the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. |
Entergy Louisiana [Member] | |
Schedule of Noncontrolling Interest [Table Text Block] | The dollar value of noncontrolling interests for Entergy Louisiana as of December 31, 2023 and 2022 are presented below. 2023 2022 (In Thousands) Entergy Louisiana Noncontrolling Interests Restoration Law Trust I (a) $30,488 $31,735 Restoration Law Trust II (b) 14,619 — Total Noncontrolling Interests $45,107 $31,735 (a) Restoration Law Trust I (the storm trust I) was established in 2022 as part of the Act 293 securitization of Entergy Louisiana’s Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, as well as to establish a storm reserve to fund a portion of Hurricane Ida storm restoration costs. The storm trust I holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust I and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana May 2022 storm cost securitization. (b) Restoration Law Trust II (the storm trust II) was established in 2023 as part of the Act 293 securitization of Entergy Louisiana’s remaining Hurricane Ida storm restoration costs. The storm trust II holds preferred membership interests issued by Entergy Finance Company, and Entergy Finance Company is required to make annual distributions (dividends) on the preferred membership interests. These annual dividends paid on the Entergy Finance Company preferred membership interests are distributed 1% to the LURC and 99% to Entergy Louisiana. Entergy Louisiana, as the primary beneficiary, consolidates the storm trust II and the LURC’s 1% beneficial interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Louisiana and Entergy. See Note 2 to the financial statements for a discussion of the Entergy Louisiana March 2023 storm cost securitization. |
Entergy Mississippi [Member] | |
Schedule of Noncontrolling Interest [Table Text Block] | The dollar value of noncontrolling interest for Entergy Mississippi as of December 31, 2023 and 2022 is presented below. 2023 2022 (In Thousands) Entergy Mississippi Noncontrolling Interest MS Sunflower Partnership, LLC (a) $18,753 $3,347 Total Noncontrolling Interest $18,753 $3,347 (a) MS Sunflower Partnership, LLC is a tax equity partnership between Entergy Mississippi and a tax equity investor which was formed to acquire and own the Sunflower Solar facility. Entergy Mississippi, as the managing member, consolidates MS Sunflower Partnership, LLC and the tax equity investor’s interest is presented as noncontrolling interest in the consolidated financial statements for Entergy Mississippi and Entergy. Entergy Mississippi uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting. |
Common Equity (Tables)
Common Equity (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Common Stock and Treasury Stock Shares Activity Roll Forward [Table Text Block] | Common stock and treasury stock shares activity for Entergy for 2023, 2022, and 2021 is as follows: 2023 2022 2021 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 279,653,929 68,477,429 271,965,510 69,312,326 270,035,180 69,790,346 Issuances: Equity Distribution Program 1,321,419 — 7,688,419 — 1,930,330 — Employee Stock-Based Compensation Plans — (336,621) — (818,366) — (461,903) Directors’ Plan — (14,030) — (16,531) — (16,117) Ending Balance, December 31 280,975,348 68,126,778 279,653,929 68,477,429 271,965,510 69,312,326 |
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block] | The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2023: Pension and Other Postretirement Liabilities (In Thousands) Beginning balance, January 1, 2023 ($191,754) Other comprehensive income (loss) before reclassifications 36,404 Amounts reclassified from accumulated other comprehensive income (loss) (7,110) Net other comprehensive income (loss) for the period 29,294 Ending balance, December 31, 2023 ($162,460) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2022 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2022 ($1,035) ($338,647) $7,154 ($332,528) Other comprehensive income (loss) before reclassifications 908 112,944 (12,997) 100,855 Amounts reclassified from accumulated other comprehensive income (loss) 127 33,949 5,843 39,919 Net other comprehensive income (loss) for the period 1,035 146,893 (7,154) 140,774 Ending balance, December 31, 2022 $— ($191,754) $— ($191,754) |
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block] | Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Cash flow hedges net unrealized loss Interest rate swaps $— ($161) Miscellaneous - net Total realized loss on cash flow hedges — (161) Income taxes — 34 Income taxes Total realized loss on cash flow hedges (net of tax) $— ($127) Pension and other postretirement liabilities Amortization of prior-service costs $13,586 $15,337 (a) Amortization of net gain (loss) 6,590 (33,859) (a) Settlement loss (10,848) (25,321) (a) Total amortization and settlement loss 9,328 (43,843) Income taxes (2,218) 9,894 Income taxes Total amortization and settlement loss (net of tax) $7,110 ($33,949) Net unrealized investment gain (loss) Realized loss $— ($9,245) Interest and investment income Income taxes — 3,402 Income taxes Total realized investment loss (net of tax) $— ($5,843) Total reclassifications for the period (net of tax) $7,110 ($39,919) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Entergy Louisiana [Member] | |
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block] | The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the years ended December 31, 2023 and 2022: Pension and Other Postretirement Liabilities 2023 2022 (In Thousands) Beginning balance, January 1, $55,370 $8,278 Other comprehensive income (loss) before reclassifications 5,603 48,087 Amounts reclassified from accumulated other comprehensive income (loss) (6,175) (995) Net other comprehensive income (loss) for the period (572) 47,092 Ending balance, December 31, $54,798 $55,370 |
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block] | Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2023 and 2022 are as follows: Amounts reclassified from AOCI Income Statement Location 2023 2022 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $3,804 $4,630 (a) Amortization of net gain (loss) 6,263 (927) (a) Settlement loss (1,617) (2,342) (a) Total amortization and settlement loss 8,450 1,361 Income taxes (2,275) (366) Income taxes Total amortization and settlement loss (net of tax) 6,175 995 Total reclassifications for the period (net of tax) $6,175 $995 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. |
Commitments And Contingencies (
Commitments And Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Entergy Arkansas [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Entergy Louisiana [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Entergy Mississippi [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Entergy New Orleans [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Entergy Texas [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
System Energy [Member] | |
Schedule of Loss Contingencies by Contingency [Table Text Block] | Effective April 1, 2023, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $19.4 Entergy Louisiana $36.6 Entergy Mississippi $0.1 Entergy New Orleans $0.1 Entergy Texas N/A System Energy $14.3 |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Entergy Arkansas [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Entergy Louisiana [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Entergy Mississippi [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Entergy New Orleans [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Entergy Texas [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
System Energy [Member] | |
Schedule Of Regulatory Assets And Liabilities [Table Text Block] | In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2023 2022 (In Millions) Entergy Arkansas $319.7 $267.1 Entergy Louisiana $262.3 $418.8 Entergy Mississippi $188.0 $159.4 Entergy New Orleans $61.1 $56.3 Entergy Texas $77.5 $62.9 System Energy $102.1 $94.4 |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by Entergy were as follows: Liabilities as of December 31, 2022 Accretion Change in Liabilities as of December 31, 2023 (In Millions) Entergy $4,271.5 $219.4 $14.9 $4,505.8 Entergy Arkansas $1,472.7 $87.4 $— $1,560.1 Entergy Louisiana $1,736.8 $88.6 $10.8 $1,836.2 Entergy Mississippi $7.8 $0.4 $— $8.2 Entergy New Orleans $— $0.5 $4.1 $4.6 Entergy Texas $11.1 $0.6 $— $11.7 System Energy $1,042.5 $41.7 $— $1,084.2 Liabilities as Accretion Change in Spending Dispositions Liabilities as (In Millions) Entergy $4,757.1 $236.0 ($0.5) ($13.3) ($707.8) $4,271.5 Utility Entergy Arkansas $1,390.4 $82.3 $— $— $— $1,472.7 Entergy Louisiana $1,653.2 $84.1 $2.8 ($3.3) $— $1,736.8 Entergy Mississippi $10.3 $0.6 $— ($3.1) $— $7.8 Entergy New Orleans $4.0 $0.1 $— ($4.1) $— $— Entergy Texas $8.5 $0.5 $2.1 $— $— $11.1 System Energy $1,007.6 $40.2 ($5.4) $— $— $1,042.5 Non-Utility Operations Big Rock Point $42.0 $2.0 $— ($1.2) ($42.8) (b) $— Palisades $640.4 $31.0 $— ($1.6) ($669.8) (b) $— Other (a) $0.6 $— $— $— $— $0.6 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Big Rock Point Site and Palisades in June 2022. |
Leases (Tables)
Leases (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Lease, Cost [Table Text Block] | Entergy incurred the following total lease costs for the years ended December 31, 2023 and 2022: 2023 2022 (In Thousands) Operating lease cost $68,136 $65,463 Finance lease cost: Amortization of right-of-use assets $15,193 $13,493 Interest on lease liabilities $3,639 $2,702 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheets as of December 31, 2023 and 2022: 2023 2022 (In Thousands) Current liabilities: Operating leases $ 60,789 $ 56,566 Finance leases $ 16,671 $ 13,824 Non-current liabilities: Operating leases $ 146,627 $ 134,886 Finance leases $ 72,215 $ 54,875 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of Entergy at December 31, 2023 and 2022: 2023 2022 Weighted-average remaining lease terms: Operating leases 4.46 4.32 Finance leases 8.61 5.63 Weighted-average discount rate: Operating leases 4.10 % 3.61 % Finance leases 4.64 % 3.95 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for Entergy as of December 31, 2023 are as follows: Operating Leases Finance Leases (In Thousands) 2024 $67,411 $19,937 2025 53,183 18,243 2026 44,744 16,392 2027 32,552 13,920 2028 14,038 11,342 Years thereafter 14,105 33,409 Minimum lease payments 226,033 113,243 Less: amount representing interest 18,617 24,357 Present value of net minimum lease payments $207,416 $88,886 |
Entergy Arkansas [Member] | |
Lease, Assets [Table Text Block] | Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 |
Lease, Cost [Table Text Block] | The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 |
Entergy Louisiana [Member] | |
Lease, Assets [Table Text Block] | Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 |
Lease, Cost [Table Text Block] | The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 |
Entergy Mississippi [Member] | |
Lease, Assets [Table Text Block] | Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 |
Lease, Cost [Table Text Block] | The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 |
Entergy New Orleans [Member] | |
Lease, Assets [Table Text Block] | Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 |
Lease, Cost [Table Text Block] | The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 |
Entergy Texas [Member] | |
Lease, Assets [Table Text Block] | Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 Operating leases $61,718 $54,047 $25,470 $6,119 $21,321 Finance leases $17,622 $21,438 $22,661 $4,779 $8,714 2022 Operating leases $56,000 $46,137 $23,624 $5,906 $17,076 Finance leases $13,493 $18,540 $8,578 $4,342 $8,094 |
Lease, Cost [Table Text Block] | The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $17,065 $16,906 $7,837 $1,912 $7,290 Finance lease cost: Amortization of right-of-use assets $3,633 $4,835 $2,227 $1,025 $1,786 Interest on lease liabilities $545 $729 $973 $150 $284 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,435 $15,016 $7,510 $1,755 $5,624 Finance lease cost: Amortization of right-of-use assets $3,048 $4,259 $1,962 $906 $1,629 Interest on lease liabilities $402 $592 $261 $134 $230 |
Lease, Liabilities [Table Text Block] | The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $15,514 $14,771 $6,754 $1,681 $6,023 Finance leases $3,743 $4,870 $3,059 $991 $1,865 Non-current liabilities: Operating leases $46,211 $39,282 $18,722 $4,377 $15,304 Finance leases $13,879 $16,568 $19,602 $3,788 $6,849 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $14,140 $13,554 $6,540 $1,650 $5,640 Finance leases $2,985 $4,276 $1,974 $918 $1,654 Non-current liabilities: Operating leases $41,874 $32,588 $17,098 $4,217 $11,441 Finance leases $10,508 $14,264 $6,604 $3,424 $6,440 |
Lease, Terms and Discount Rate [Table Text Block] | The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.62 4.60 5.34 6.38 4.44 Finance leases 5.57 5.40 17.82 5.73 5.49 Weighted-average discount rate: Operating leases 4.04 % 4.01 % 4.08 % 4.02 % 4.43 % Finance leases 3.77 % 3.85 % 5.08 % 3.69 % 3.76 % The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted-average remaining lease terms: Operating leases 4.55 4.26 5.31 6.08 3.84 Finance leases 5.32 5.27 5.15 5.72 5.67 Weighted-average discount rate: Operating leases 3.43 % 3.24 % 3.52 % 3.50 % 3.63 % Finance leases 2.93 % 3.15 % 2.87 % 3.04 % 3.07 % |
Lease, Maturity [Table Text Block] | Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $17,399 $16,539 $7,652 $1,867 $6,828 2025 15,716 13,908 6,846 1,442 5,892 2026 13,855 11,374 5,409 1,080 4,736 2027 10,587 8,493 4,105 704 2,834 2028 4,597 4,595 2,212 476 1,563 Years thereafter 4,598 4,035 2,421 1,376 1,672 Minimum lease payments 66,752 58,944 28,645 6,945 23,525 Less: amount representing interest 5,027 4,891 3,170 887 2,198 Present value of net minimum lease payments $61,725 $54,053 $25,475 $6,058 $21,327 Finance Leases Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2024 $4,600 $5,692 $3,388 $1,148 $2,139 2025 4,179 5,037 3,093 1,016 1,975 2026 3,747 4,279 2,775 932 1,739 2027 3,088 3,389 2,322 796 1,413 2028 2,245 2,545 1,908 603 1,145 Years thereafter 2,918 3,199 23,562 812 1,222 Minimum lease payments 20,777 24,141 37,048 5,307 9,633 Less: amount representing interest 3,155 2,703 14,387 528 919 Present value of net minimum lease payments $17,622 $21,438 $22,661 $4,779 $8,714 |
Retirement, Other Postretirem_2
Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Entergy Corporation and its subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2023 2022 2021 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $101,182 $138,085 $165,278 Interest cost on projected benefit obligation 298,281 235,805 191,107 Expected return on assets (388,030) (402,504) (424,572) Recognized net loss 81,919 188,683 334,124 Settlement charges 160,387 230,389 205,878 Net pension cost $253,739 $390,458 $471,815 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($213,636) $6,113 ($448,532) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (81,919) (188,683) (334,124) Settlement charge (160,387) (230,389) (205,878) Total ($455,942) ($412,959) ($988,534) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($202,203) ($22,501) ($516,719) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $6,166,106 $8,409,620 Service cost 101,182 138,085 Interest cost 298,281 235,805 Actuarial (gain)/loss 123,237 (1,660,463) Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Balance at December 31 $5,915,404 $6,166,106 Change in Plan Assets Fair value of assets at January 1 $5,242,098 $6,993,110 Actual return on plan assets 724,903 (1,264,071) Employer contributions 267,002 470,000 Benefits paid (including settlement lump sum benefit payments of ($410,110) in 2023 and ($604,753) in 2022) (773,402) (956,941) Fair value of assets at December 31 $5,460,601 $5,242,098 Funded status ($454,803) ($924,008) Amount recognized in the balance sheet (funded status) Non-current liabilities ($454,803) ($924,008) Amount recognized as a regulatory asset Net loss $1,447,978 $1,842,348 Amount recognized as AOCI (before tax) Net loss $347,268 $408,839 |
Reclassification out of Accumulated Other Comprehensive Income, Amortization [Table Text Block] | Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2023: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $14,038 ($452) $13,586 Amortization of gain (loss) (4,407) 11,590 (593) 6,590 Settlement loss (7,844) — (3,004) (10,848) ($12,251) $25,628 ($4,049) $9,328 Entergy Louisiana Amortization of prior service cost $— $3,804 $— $3,804 Amortization of gain (loss) (792) 7,057 (2) 6,263 Settlement loss (1,617) — — (1,617) ($2,409) $10,861 ($2) $8,450 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2022: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $16,052 ($715) $15,337 Amortization of loss (30,147) (2,381) (1,331) (33,859) Settlement loss (23,636) — (1,685) (25,321) ($53,783) $13,671 ($3,731) ($43,843) Entergy Louisiana Amortization of prior service cost $— $4,630 $— $4,630 Amortization of gain (loss) (1,669) 744 (2) (927) Settlement loss (2,342) — — (2,342) ($4,011) $5,374 ($2) $1,361 |
Defined Benefit Plan Assets Target Allocations [Table Text Block] | Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2023 and 2022 and the target asset allocation and ranges for 2023 are as follows: Pension Asset Allocation Target Range Actual 2023 Actual 2022 Domestic Equity Securities 32% 26% to 38% 33% 42% International Equity Securities 17% 14% to 20% 18% 22% Intermediate Fixed Income Securities 8% 7% to 9% 9% 11% Long Duration Fixed Income Securities 43% 39% to 47% 40% 22% Other —% —% to 10% —% 3% Postretirement Asset Allocation Non-Taxable and Taxable Target Range Actual 2023 Actual 2022 Domestic Equity Securities 25% 20% to 30% 28% 25% International Equity Securities 17% 12% to 22% 17% 18% Fixed Income Securities 58% 53% to 63% 55% 57% Other —% —% to 5% —% —% |
Defined Benefit Plan Fair Value Of Plan Assets [Table Text Block] | The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2023, and December 31, 2022, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate. Qualified Defined Benefit Pension Plan Trusts 2023 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Corporate stocks: Preferred $10,827 (b) $— $— $10,827 Common 715,452 (b) — — 715,452 Common collective trusts (c) 2,066,247 Fixed income securities: U.S. Government securities — 1,085,231 (a) — 1,085,231 Corporate debt instruments — 924,904 (a) — 924,904 Registered investment companies (e) 34,364 (d) 2,718 (d) — 657,691 Other 774 (f) 78,883 (f) — 79,657 Other: Insurance company general account (unallocated contracts) — 5,899 (g) — 5,899 Total investments $761,417 $2,097,635 $— $5,545,908 Cash 1,488 Other pending transactions (22,404) Less: Other postretirement assets included in total investments (64,391) Total fair value of qualified pension assets $5,460,601 2022 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Corporate stocks: Preferred $12,178 (b) $— $— $12,178 Common 807,437 (b) — — 807,437 Common collective trusts (c) 2,516,688 Fixed income securities: U.S. Government securities — 673,348 (a) — 673,348 Corporate debt instruments — 525,184 (a) — 525,184 Registered investment companies (e) 221,582 (d) 2,595 (d) — 750,454 Other — 15,395 (f) — 15,395 Other: Insurance company general account (unallocated contracts) — 5,911 (g) — 5,911 Total investments $1,041,197 $1,222,433 $— $5,306,595 Cash 10,601 Other pending transactions (13,813) Less: Other postretirement assets included in total investments (61,285) Total fair value of qualified pension assets $5,242,098 Other Postretirement Trusts 2023 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Common collective trust (c) $276,560 Fixed income securities: U.S. Government securities $80,219 (b) $84,521 (a) $— 164,740 Corporate debt instruments — 106,523 (a) — 106,523 Registered investment companies 548 (d) — — 548 Other — 57,511 (f) — 57,511 Total investments $80,767 $248,555 $— $605,882 Other pending transactions 2,868 Plus: Other postretirement assets included in the investments of the qualified pension trust 64,391 Total fair value of other postretirement assets $673,141 2022 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Common collective trust (c) $241,676 Fixed income securities: U.S. Government securities $69,503 (b) $78,436 (a) $— 147,939 Corporate debt instruments — 113,273 (a) — 113,273 Registered investment companies 3,016 (d) — — 3,016 Other — 56,149 (f) — 56,149 Total investments $72,519 $247,858 $— $562,053 Other pending transactions 486 Plus: Other postretirement assets included in the investments of the qualified pension trust 61,285 Total fair value of other postretirement assets $623,824 (a) Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes. (b) Common stocks, preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices. (c) The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. (d) Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities valued at the daily closing price as reported by the fund. These funds are required to publish their daily net asset value and to transact at that price. The money market mutual funds held by the trusts are deemed to be actively traded. Certain registered investment companies are recorded at contract value, which approximates fair value. (e) Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. (f) The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes. (g) The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust. |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefits obligations at December 31, 2023, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid over the next ten years for Entergy Corporation and its subsidiaries will be as follows: Estimated Future Benefits Payments Qualified Pension Non-Qualified Pension Other Postretirement (In Thousands) Year(s) 2024 $463,557 $13,802 $74,649 2025 $449,803 $10,894 $70,720 2026 $450,945 $8,507 $67,105 2027 $449,510 $14,374 $63,949 2028 $450,827 $9,325 $61,234 2029 - 2033 $2,222,959 $36,584 $283,477 |
Defined Benefit Plan Weighted Average Assumptions Used In Calculating Benefit Obligation [Table Text Block] | The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefits APBO as of December 31, 2023 and 2022 were as follows: 2023 2022 Weighted-average discount rate: Qualified pension 5.02% - 5.10% Blended 5.06% 5.21% - 5.27% Blended 5.24% Other postretirement 5.01% 5.20% Non-qualified pension 4.68% 4.98% Weighted-average rate of increase in future compensation levels 3.98% - 4.40% 3.98% - 4.40% Interest crediting rate 4.00% 4.00% Assumed health care trend rate: Pre-65 6.95% 6.65% Post-65 7.88% 7.50% Ultimate health care cost trend rate 4.75% 4.75% Year ultimate health care cost trend rate is reached and beyond: Pre-65 2032 2032 Post-65 2032 2032 |
Defined Benefit Plan Weighted Average Assumptions Used In Calculating Net Periodic Benefit Cost [Table Text Block] | The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefits costs for 2023, 2022, and 2021 were as follows: 2023 2022 2021 Weighted-average discount rate: Qualified pension: Service cost 5.26% 3.07% 2.81% Interest cost 5.16% 2.49% 2.08% Other postretirement: Service cost 5.00% 3.20% 2.98% Interest cost 5.09% 2.31% 1.86% Non-qualified pension: Service cost 5.31% 4.94% 1.48% Interest cost 5.30% 5.03% 2.14% Weighted-average rate of increase in future compensation levels 3.98% - 4.40% 3.98% - 4.40% 3.98% - 4.40% Expected long-term rate of return on plan assets: Pension assets 7.00% 6.75% 6.75% Other postretirement non-taxable assets 6.00% - 7.00% 5.75% - 6.75% 6.00% - 6.75% Other postretirement taxable assets 5.25% 4.75% 5.00% Assumed health care trend rate: Pre-65 6.65% 5.65% 5.87% Post-65 7.50% 5.90% 6.31% Ultimate health care cost trend rate 4.75% 4.75% 4.75% Year ultimate health care cost trend rate is reached and beyond: Pre-65 2032 2032 2030 Post-65 2032 2032 2028 |
Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Entergy Corporation’s and its subsidiaries’ total 2023, 2022, and 2021 other postretirement benefits costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2023 2022 2021 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $14,654 $24,734 $26,578 Interest cost on accumulated postretirement benefits obligation (APBO) 42,272 27,306 21,278 Expected return on assets (36,732) (43,420) (43,220) Amortization of prior service credit (22,558) (25,550) (33,069) Recognized net (gain)/loss (11,446) 4,333 2,853 Net other postretirement benefits income ($13,810) ($12,597) ($25,580) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period ($4,434) ($858) ($3,168) Net (gain)/loss (44,441) (131,524) 6,210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 22,558 25,550 33,069 Amortization of net gain/(loss) 11,446 (4,333) (2,853) Total ($14,871) ($111,165) $33,258 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($28,681) ($123,762) $7,678 |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Thousands) Change in APBO Balance at January 1 $865,854 $1,189,682 Service cost 14,654 24,734 Interest cost 42,272 27,306 Plan amendments (4,434) (858) Plan participant contributions 18,669 22,486 Actuarial gain (4,303) (297,128) Benefits paid (95,348) (100,632) Medicare Part D subsidy received 280 264 Balance at December 31 $837,644 $865,854 Change in Plan Assets Fair value of assets at January 1 $623,824 $771,319 Actual return on plan assets 76,870 (122,184) Employer contributions 49,126 52,835 Plan participant contributions 18,669 22,486 Benefits paid (95,348) (100,632) Fair value of assets at December 31 $673,141 $623,824 Funded status ($164,503) ($242,030) Amounts recognized in the balance sheet Current liabilities ($45,706) ($42,484) Non-current liabilities (118,797) (199,546) Total funded status ($164,503) ($242,030) Amounts recognized as a regulatory asset Prior service credit ($21,465) ($29,323) Net (gain)/loss (33,617) 16,956 ($55,082) ($12,367) Amounts recognized as AOCI (before tax) Prior service credit ($34,899) ($45,167) Net gain (116,078) (133,656) ($150,977) ($178,823) |
Entergy Arkansas [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
Schedule Of Contributions To Defined Contribution Plans [Table Text Block] | The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $5,866 $7,757 $3,534 $1,383 $3,380 2022 $5,124 $7,138 $3,194 $1,223 $2,938 2021 $4,820 $6,678 $3,045 $1,140 $2,699 |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $637 $99 $808 $132 $253 2022 $282 $102 $321 $114 $1,320 2021 $343 $307 $365 $30 $615 |
Schedule of Changes in Projected Benefit Obligations [Table Text Block] | The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $2,313 $2,574 $3,369 $1,034 $3,762 2022 $2,433 $1,197 $3,830 $1,024 $3,850 |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $1,935 $2,494 $3,187 $814 $3,701 2022 $2,192 $1,197 $3,594 $719 $3,776 |
Schedule of Amounts Recognized in Balance Sheet [Table Text Block] | The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($276) ($308) ($474) ($106) ($448) Non-current liabilities (2,037) (2,266) (2,895) (928) (3,314) Total funded status ($2,313) ($2,574) ($3,369) ($1,034) ($3,762) Regulatory asset/(liability) $857 $1,604 $1,303 $5 ($2,526) Accumulated other comprehensive income (before taxes) $— $67 $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($234) ($184) ($214) ($32) ($448) Non-current liabilities (2,199) (1,013) (3,616) (992) (3,402) Total funded status ($2,433) ($1,197) ($3,830) ($1,024) ($3,850) Regulatory asset/(liability) $512 $119 $1,291 $111 ($2,615) Accumulated other comprehensive income (before taxes) $— $5 $— $— $— |
Entergy Louisiana [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Reclassification out of Accumulated Other Comprehensive Income, Amortization [Table Text Block] | Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2023: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $14,038 ($452) $13,586 Amortization of gain (loss) (4,407) 11,590 (593) 6,590 Settlement loss (7,844) — (3,004) (10,848) ($12,251) $25,628 ($4,049) $9,328 Entergy Louisiana Amortization of prior service cost $— $3,804 $— $3,804 Amortization of gain (loss) (792) 7,057 (2) 6,263 Settlement loss (1,617) — — (1,617) ($2,409) $10,861 ($2) $8,450 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2022: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $16,052 ($715) $15,337 Amortization of loss (30,147) (2,381) (1,331) (33,859) Settlement loss (23,636) — (1,685) (25,321) ($53,783) $13,671 ($3,731) ($43,843) Entergy Louisiana Amortization of prior service cost $— $4,630 $— $4,630 Amortization of gain (loss) (1,669) 744 (2) (927) Settlement loss (2,342) — — (2,342) ($4,011) $5,374 ($2) $1,361 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
Schedule Of Contributions To Defined Contribution Plans [Table Text Block] | The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $5,866 $7,757 $3,534 $1,383 $3,380 2022 $5,124 $7,138 $3,194 $1,223 $2,938 2021 $4,820 $6,678 $3,045 $1,140 $2,699 |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $637 $99 $808 $132 $253 2022 $282 $102 $321 $114 $1,320 2021 $343 $307 $365 $30 $615 |
Schedule of Changes in Projected Benefit Obligations [Table Text Block] | The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $2,313 $2,574 $3,369 $1,034 $3,762 2022 $2,433 $1,197 $3,830 $1,024 $3,850 |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $1,935 $2,494 $3,187 $814 $3,701 2022 $2,192 $1,197 $3,594 $719 $3,776 |
Schedule of Amounts Recognized in Balance Sheet [Table Text Block] | The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($276) ($308) ($474) ($106) ($448) Non-current liabilities (2,037) (2,266) (2,895) (928) (3,314) Total funded status ($2,313) ($2,574) ($3,369) ($1,034) ($3,762) Regulatory asset/(liability) $857 $1,604 $1,303 $5 ($2,526) Accumulated other comprehensive income (before taxes) $— $67 $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($234) ($184) ($214) ($32) ($448) Non-current liabilities (2,199) (1,013) (3,616) (992) (3,402) Total funded status ($2,433) ($1,197) ($3,830) ($1,024) ($3,850) Regulatory asset/(liability) $512 $119 $1,291 $111 ($2,615) Accumulated other comprehensive income (before taxes) $— $5 $— $— $— |
Entergy Mississippi [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
Schedule Of Contributions To Defined Contribution Plans [Table Text Block] | The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $5,866 $7,757 $3,534 $1,383 $3,380 2022 $5,124 $7,138 $3,194 $1,223 $2,938 2021 $4,820 $6,678 $3,045 $1,140 $2,699 |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $637 $99 $808 $132 $253 2022 $282 $102 $321 $114 $1,320 2021 $343 $307 $365 $30 $615 |
Schedule of Changes in Projected Benefit Obligations [Table Text Block] | The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $2,313 $2,574 $3,369 $1,034 $3,762 2022 $2,433 $1,197 $3,830 $1,024 $3,850 |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $1,935 $2,494 $3,187 $814 $3,701 2022 $2,192 $1,197 $3,594 $719 $3,776 |
Schedule of Amounts Recognized in Balance Sheet [Table Text Block] | The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($276) ($308) ($474) ($106) ($448) Non-current liabilities (2,037) (2,266) (2,895) (928) (3,314) Total funded status ($2,313) ($2,574) ($3,369) ($1,034) ($3,762) Regulatory asset/(liability) $857 $1,604 $1,303 $5 ($2,526) Accumulated other comprehensive income (before taxes) $— $67 $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($234) ($184) ($214) ($32) ($448) Non-current liabilities (2,199) (1,013) (3,616) (992) (3,402) Total funded status ($2,433) ($1,197) ($3,830) ($1,024) ($3,850) Regulatory asset/(liability) $512 $119 $1,291 $111 ($2,615) Accumulated other comprehensive income (before taxes) $— $5 $— $— $— |
Entergy New Orleans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
Schedule Of Contributions To Defined Contribution Plans [Table Text Block] | The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $5,866 $7,757 $3,534 $1,383 $3,380 2022 $5,124 $7,138 $3,194 $1,223 $2,938 2021 $4,820 $6,678 $3,045 $1,140 $2,699 |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $637 $99 $808 $132 $253 2022 $282 $102 $321 $114 $1,320 2021 $343 $307 $365 $30 $615 |
Schedule of Changes in Projected Benefit Obligations [Table Text Block] | The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $2,313 $2,574 $3,369 $1,034 $3,762 2022 $2,433 $1,197 $3,830 $1,024 $3,850 |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $1,935 $2,494 $3,187 $814 $3,701 2022 $2,192 $1,197 $3,594 $719 $3,776 |
Schedule of Amounts Recognized in Balance Sheet [Table Text Block] | The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($276) ($308) ($474) ($106) ($448) Non-current liabilities (2,037) (2,266) (2,895) (928) (3,314) Total funded status ($2,313) ($2,574) ($3,369) ($1,034) ($3,762) Regulatory asset/(liability) $857 $1,604 $1,303 $5 ($2,526) Accumulated other comprehensive income (before taxes) $— $67 $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($234) ($184) ($214) ($32) ($448) Non-current liabilities (2,199) (1,013) (3,616) (992) (3,402) Total funded status ($2,433) ($1,197) ($3,830) ($1,024) ($3,850) Regulatory asset/(liability) $512 $119 $1,291 $111 ($2,615) Accumulated other comprehensive income (before taxes) $— $5 $— $— $— |
Entergy Texas [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
Schedule Of Contributions To Defined Contribution Plans [Table Text Block] | The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $5,866 $7,757 $3,534 $1,383 $3,380 2022 $5,124 $7,138 $3,194 $1,223 $2,938 2021 $4,820 $6,678 $3,045 $1,140 $2,699 |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $637 $99 $808 $132 $253 2022 $282 $102 $321 $114 $1,320 2021 $343 $307 $365 $30 $615 |
Schedule of Changes in Projected Benefit Obligations [Table Text Block] | The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $2,313 $2,574 $3,369 $1,034 $3,762 2022 $2,433 $1,197 $3,830 $1,024 $3,850 |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2023 $1,935 $2,494 $3,187 $814 $3,701 2022 $2,192 $1,197 $3,594 $719 $3,776 |
Schedule of Amounts Recognized in Balance Sheet [Table Text Block] | The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($276) ($308) ($474) ($106) ($448) Non-current liabilities (2,037) (2,266) (2,895) (928) (3,314) Total funded status ($2,313) ($2,574) ($3,369) ($1,034) ($3,762) Regulatory asset/(liability) $857 $1,604 $1,303 $5 ($2,526) Accumulated other comprehensive income (before taxes) $— $67 $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($234) ($184) ($214) ($32) ($448) Non-current liabilities (2,199) (1,013) (3,616) (992) (3,402) Total funded status ($2,433) ($1,197) ($3,830) ($1,024) ($3,850) Regulatory asset/(liability) $512 $119 $1,291 $111 ($2,615) Accumulated other comprehensive income (before taxes) $— $5 $— $— $— |
System Energy [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $18,461 $24,716 $5,775 $1,955 $4,328 $5,749 Interest cost on projected benefit obligation 56,026 60,346 15,402 6,747 12,726 13,852 Expected return on assets (70,574) (75,757) (19,423) (8,798) (16,641) (17,585) Recognized net loss 19,400 19,797 5,719 1,694 4,075 4,236 Settlement charges 26,137 40,437 12,242 2,080 11,230 6,375 Net pension cost $49,450 $69,539 $19,715 $3,678 $15,718 $12,627 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($30,674) ($71,016) ($20,220) ($3,183) ($16,759) ($3,268) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (19,400) (19,797) (5,719) (1,694) (4,075) (4,236) Settlement charge (26,137) (40,437) (12,242) (2,080) (11,230) (6,375) Total ($76,211) ($131,250) ($38,181) ($6,957) ($32,064) ($13,879) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($26,761) ($61,711) ($18,466) ($3,279) ($16,346) ($1,252) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $25,210 $33,520 $8,043 $2,745 $5,999 $7,746 Interest cost on projected benefit obligation 45,378 49,330 12,979 5,491 10,729 11,286 Expected return on assets (75,820) (82,478) (20,168) (9,920) (18,317) (18,173) Recognized net loss 43,597 41,711 12,594 4,787 9,013 10,938 Settlement charges 36,409 58,550 15,786 6,676 22,411 9,905 Net pension cost $74,774 $100,633 $29,234 $9,779 $29,835 $21,702 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss $28,365 ($15,604) ($4,743) $525 $13,363 ($7,063) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (43,597) (41,711) (12,594) (4,787) (9,013) (10,938) Settlement charge (36,409) (58,550) (15,786) (6,676) (22,411) (9,905) Total ($51,641) ($115,865) ($33,123) ($10,938) ($18,061) ($27,906) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $23,133 ($15,232) ($3,889) ($1,159) $11,774 ($6,204) 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Service cost 18,461 24,716 5,775 1,955 4,328 5,749 Interest cost 56,026 60,346 15,402 6,747 12,726 13,852 Actuarial (gain)/loss 39,643 1,925 (328) 4,590 (1,416) 14,522 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Balance at December 31 $1,117,585 $1,173,283 $295,942 $133,950 $239,984 $286,558 Change in Plan Assets Fair value of assets at January 1 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Actual return on plan assets 140,891 148,698 39,315 16,571 31,984 35,375 Employer contributions 54,468 44,565 21,110 1,420 5,314 15,543 Benefits paid (a) (164,643) (170,126) (45,901) (19,778) (41,219) (35,867) Fair value of assets at December 31 $991,894 $1,058,711 $280,260 $117,923 $222,496 $255,443 Funded status ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($125,691) ($114,572) ($15,682) ($16,027) ($17,488) ($31,115) Amounts recognized as regulatory asset Net loss $485,113 $319,116 $102,208 $44,911 $63,665 $111,996 Amounts recognized as AOCI (before tax) Net loss $— $13,296 $— $— $— $— (a) Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy. 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Service cost 25,210 33,520 8,043 2,745 5,999 7,746 Interest cost 45,378 49,330 12,979 5,491 10,729 11,286 Actuarial gain (280,691) (357,572) (88,303) (40,462) (65,795) (81,504) Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Balance at December 31 $1,168,098 $1,256,422 $320,994 $140,436 $265,565 $288,302 Change in Plan Assets Fair value of assets at January 1 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Actual return on plan assets (233,236) (259,490) (63,392) (31,067) (60,841) (56,267) Employer contributions 92,971 53,658 33,287 1,129 2,513 28,619 Benefits paid (a) (201,145) (205,252) (60,583) (22,718) (57,170) (44,020) Fair value of assets at December 31 $961,178 $1,035,574 $265,736 $119,710 $226,417 $240,392 Funded status ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($206,920) ($220,848) ($55,258) ($20,726) ($39,148) ($47,910) Amounts recognized as regulatory asset Net loss $561,323 $445,116 $140,389 $51,868 $95,729 $125,876 Amounts recognized as AOCI (before tax) Net loss $— $18,546 $— $— $— $— |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows: December 31, 2023 2022 (In Thousands) Entergy Arkansas $1,048,901 $1,008,152 Entergy Louisiana $1,085,318 $1,146,561 Entergy Mississippi $273,338 $292,596 Entergy New Orleans $125,878 $128,499 Entergy Texas $225,379 $245,428 System Energy $267,432 $269,583 |
Schedule Of Estimated Future Benefits Payments And Estimated Future Medicare Subsidy Receipts [Table Text Block] | Based upon the same assumptions, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $90,682 $95,706 $25,534 $11,300 $21,807 $24,163 2025 $89,113 $92,420 $24,816 $10,799 $21,019 $22,053 2026 $88,427 $92,499 $25,210 $10,910 $21,268 $21,612 2027 $87,845 $91,485 $24,686 $10,566 $20,407 $22,665 2028 $87,719 $91,450 $24,147 $10,458 $20,074 $22,107 2029 - 2033 $429,882 $444,131 $115,629 $48,870 $92,182 $109,712 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2024 $276 $308 $474 $106 $448 2025 $474 $301 $547 $143 $423 2026 $160 $288 $461 $139 $445 2027 $149 $265 $642 $224 $395 2028 $288 $270 $395 $141 $369 2029 - 2033 $938 $941 $1,326 $529 $1,524 Estimated Future Other Postretirement Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2024 $13,697 $15,049 $3,521 $2,200 $5,187 $2,811 2025 $12,913 $14,380 $3,386 $2,086 $4,874 $2,668 2026 $12,342 $13,676 $3,256 $1,942 $4,436 $2,434 2027 $11,767 $13,037 $3,126 $1,785 $4,215 $2,320 2028 $11,424 $12,348 $3,121 $1,640 $3,937 $2,266 2029 - 2033 $54,789 $57,264 $14,563 $7,297 $17,857 $11,270 |
Schedule of Expected Benefit Payments [Table Text Block] | The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Other Postretirement Contributions $529 $15,049 $178 $205 $156 $34 |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,965 $3,379 $878 $235 $809 $754 Interest cost on APBO 8,002 8,931 2,170 1,160 2,597 1,726 Expected return on assets (15,113) — (4,716) (5,263) (8,776) (2,535) Amortization of prior service cost/(credit) 2,096 (3,804) (955) (916) (4,371) (293) Recognized net (gain)/loss 171 (7,057) 85 466 914 — Net other postretirement benefits (income)/cost ($1,879) $1,449 ($2,538) ($4,318) ($8,827) ($348) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service credit for the period $— ($4,434) $— $— $— $— Net gain (23,033) (458) (6,883) (7,606) (8,790) (3,942) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (2,096) 3,804 955 916 4,371 293 Amortization of net gain/(loss) (171) 7,057 (85) (466) (914) — Total ($25,300) $5,969 ($6,013) ($7,156) ($5,333) ($3,649) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($27,179) $7,418 ($8,551) ($11,474) ($14,160) ($3,997) 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,457 $5,633 $1,354 $397 $1,322 $1,239 Interest cost on APBO 5,050 5,770 1,401 694 1,596 1,116 Expected return on assets (17,930) — (5,575) (5,997) (10,273) (3,162) Amortization of prior service cost/(credit) 1,885 (4,630) (1,772) (916) (4,371) (319) Recognized net (gain)/loss 873 (744) 222 (898) 648 121 Net other postretirement benefits (income)/cost ($5,665) $6,029 ($4,370) ($6,720) ($11,078) ($1,005) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $273 $323 ($1,300) $— $— $141 Net (gain)/loss 12,894 (65,501) 6,629 17,334 22,323 1,208 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit/(cost) (1,885) 4,630 1,772 916 4,371 319 Amortization of net gain/(loss) (873) 744 (222) 898 (648) (121) Total $10,409 ($59,804) $6,879 $19,148 $26,046 $1,547 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $4,744 ($53,775) $2,509 $12,428 $14,968 $542 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/loss 196 (364) 76 (712) 398 61 Net other postretirement benefits (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss 9,956 (2,367) (2,823) (3,330) 939 210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net gain/(loss) (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows: 2023 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Service cost 2,965 3,379 878 235 809 754 Interest cost 8,002 8,931 2,170 1,160 2,597 1,726 Plan amendments — (4,434) — — — — Plan participant contributions 3,131 4,317 1,386 374 680 994 Actuarial (gain)/loss (6,403) (458) (1,650) (1,676) 337 (1,075) Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Medicare Part D subsidy received 33 46 10 5 11 13 Balance at December 31 $155,987 $170,139 $41,344 $21,685 $51,617 $33,778 Change in Plan Assets Fair value of assets at January 1 $255,117 $— $79,496 $91,140 $148,799 $42,434 Actual return on plan assets 31,743 — 9,949 11,193 17,903 5,402 Employer contributions 582 20,451 646 213 235 480 Plan participant contributions 3,131 4,317 1,386 374 680 994 Benefits paid (15,759) (24,768) (5,815) (2,384) (6,299) (3,908) Fair value of assets at December 31 $274,814 $— $85,662 $100,536 $161,318 $45,402 Funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in the balance sheet Current liabilities $— ($15,049) $— $— $— $— Non-current liabilities 118,827 (155,090) 44,318 78,851 109,701 11,624 Total funded status $118,827 ($170,139) $44,318 $78,851 $109,701 $11,624 Amounts recognized in regulatory asset Prior service cost/(credit) $4,983 $— ($2,682) ($1,982) ($11,790) ($496) Net loss/(gain) (17,980) — (4,815) (5,843) 14,542 112 ($12,997) $— ($7,497) ($7,825) $2,752 ($384) Amounts recognized in AOCI (before tax) Prior service credit $— ($12,645) $— $— $— $— Net gain — (75,709) — — — — $— ($88,354) $— $— $— $— 2022 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Service cost 4,457 5,633 1,354 397 1,322 1,239 Interest cost 5,050 5,770 1,401 694 1,596 1,116 Plan amendments 273 323 (1,300) — — 141 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Actuarial gain (54,923) (65,501) (14,465) (6,867) (16,291) (10,679) Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Medicare Part D subsidy received 42 57 6 7 16 17 Balance at December 31 $164,018 $183,126 $44,365 $23,971 $53,482 $35,274 Change in Plan Assets Fair value of assets at January 1 $315,495 $— $97,888 $111,137 $182,285 $54,650 Actual return on plan assets (49,887) — (15,519) (18,204) (28,341) (8,725) Employer contributions 1,573 16,187 759 333 (23) 944 Plan participant contributions 5,521 5,081 1,443 440 924 1,222 Benefits paid (17,585) (21,268) (5,075) (2,566) (6,046) (5,657) Fair value of assets at December 31 $255,117 $— $79,496 $91,140 $148,799 $42,434 Funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in the balance sheet Current liabilities $— ($15,356) $— $— $— $— Non-current liabilities 91,099 (167,770) 35,131 67,169 95,317 7,160 Total funded status $91,099 ($183,126) $35,131 $67,169 $95,317 $7,160 Amounts recognized in regulatory asset Prior service cost/(credit) $7,079 $— ($3,637) ($2,898) ($16,161) ($789) Net loss 5,224 — 2,153 2,229 24,246 4,054 $12,303 $— ($1,484) ($669) $8,085 $3,265 Amounts recognized in AOCI (before tax) Prior service credit $— ($12,015) $— $— $— $— Net gain — (82,308) — — — — $— ($94,323) $— $— $— $— |
Stock-Based Compensation (Table
Stock-Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for stock options for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $4.1 $4.2 $4.2 Tax benefit recognized in Entergy’s consolidated net income $1.1 $1.1 $1.1 Compensation cost capitalized as part of fixed assets and materials and supplies $1.9 $1.7 $1.5 |
Schedule of Share-Based Payment Award, Employee Stock Purchase Plan, Valuation Assumptions [Table Text Block] | The stock option weighted-average assumptions used in determining the fair values are as follows: 2023 2022 2021 Stock price volatility 24.89% 24.27% 23.93% Expected term in years 6.89 6.92 6.93 Risk-free interest rate 3.51% 1.77% 0.74% Dividend yield 4.00% 4.00% 4.00% Dividend payment per share $4.34 $4.10 $3.86 |
Share-Based Payment Arrangement, Option, Activity [Table Text Block] | A summary of stock option activity for the year ended December 31, 2023 and changes during the year are presented below: Number of Options Weighted- Aggregate Intrinsic Value Weighted- Options outstanding as of January 1, 2023 2,776,355 $96.30 Options granted 281,874 $108.47 Options exercised (111,929) $85.69 Options forfeited/expired (47,592) $110.40 Options outstanding as of December 31, 2023 2,898,708 $97.66 $31,447,529 5.66 Options exercisable as of December 31, 2023 2,191,916 $94.94 $30,475,161 4.83 Weighted-average grant-date fair value of options granted during 2023 $20.07 |
Share-Based Payment Arrangement, Option, Exercise Price Range [Table Text Block] | The following table summarizes information about stock options outstanding as of December 31, 2023: Options Outstanding Options Exercisable Range of Exercise Price As of December 31, 2023 Weighted-Average Remaining Contractual Life-Yrs. Weighted-Average Exercise Price Number Exercisable as of December 31, 2023 Weighted-Average Exercise Price $63.17 - $79.99 772,974 3.18 $73.58 772,974 $73.58 $80.00 - $99.99 972,138 5.45 $92.30 814,286 $91.61 $100.00 - $119.99 685,327 8.48 $109.14 136,387 $109.59 $120.00 - $131.72 468,269 6.08 $131.72 468,269 $131.72 $63.17 - $131.72 2,898,708 5.66 $97.66 2,191,916 $94.94 |
Restricted Awards [Member] | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for restricted stock for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $22.2 $23.2 $24.7 Tax benefit recognized in Entergy’s consolidated net income $5.7 $5.9 $6.3 Compensation cost capitalized as part of fixed assets and materials and supplies $9.7 $9.2 $9.3 |
Share-Based Payment Arrangement, Option, Exercise Price Range [Table Text Block] | The following table includes information about the restricted stock awards outstanding as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 607,723 $107.55 Granted 373,741 $108.35 Vested (294,145) $110.54 Forfeited (60,546) $105.64 Outstanding shares at December 31, 2023 626,773 $106.80 |
Long Term Incentive Awards [Member] | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for the long-term performance units for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $11.1 $16.0 $14.5 Tax benefit recognized in Entergy’s consolidated net income $2.8 $4.1 $3.7 Compensation cost capitalized as part of fixed assets and materials and supplies $5.2 $6.7 $5.8 |
Share-Based Payment Arrangement, Option, Exercise Price Range [Table Text Block] | The following table includes information about the long-term performance units outstanding at the target level as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 521,838 $129.94 Granted 156,627 $126.39 Vested (38,150) $162.14 Forfeited (159,314) $145.35 Outstanding shares at December 31, 2023 481,001 $121.12 |
Restricted Stock Units (RSUs) [Member] | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for restricted stock unit awards for each of the years presented: 2023 2022 2021 (In Millions) Compensation expense included in Entergy’s consolidated net income $2.8 $2.0 $1.9 Tax benefit recognized in Entergy’s consolidated net income $0.7 $0.5 $0.5 Compensation cost capitalized as part of fixed assets and materials and supplies $1.2 $0.8 $0.7 |
Share-Based Payment Arrangement, Option, Exercise Price Range [Table Text Block] | The following table includes information about the restricted stock unit awards outstanding as of December 31, 2023: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2023 132,407 $105.75 Granted 22,547 $102.05 Vested (6,142) $110.33 Forfeited (9,312) $103.37 Outstanding shares at December 31, 2023 139,500 $105.11 |
Business Segment Information Bu
Business Segment Information Business Segment Information (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Segment Reporting Information [Line Items] | |
Restructuring and Related Costs [Table Text Block] | Total restructuring charges in 2022 and 2021 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 Restructuring costs accrued 3 — 3 Cash paid out 40 — 40 Balance as of December 31, 2022 $— $— $— |
Entergy Corporation [Member] | |
Segment Reporting Information [Line Items] | |
Schedule of Segment Reporting Information, by Segment [Table Text Block] | Entergy’s segment financial information was as follows: 2023 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $12,022,944 $124,509 ($41) $12,147,412 Asset write-offs, impairments, and related charges (credits) $79,962 ($37,283) $— $42,679 Depreciation, amortization, and decommissioning $2,045,254 $6,423 $— $2,051,677 Interest and investment income $443,751 $18,660 ($299,685) $162,726 Interest expense $816,643 $190,468 ($705) $1,006,406 Income taxes ($374,847) ($315,688) $— ($690,535) Consolidated net income $2,510,904 $150,385 ($298,979) $2,362,310 Total assets $63,887,038 $836,598 ($5,020,240) $59,703,396 Cash paid for long-lived asset additions $4,745,918 $801 $— $4,746,719 2022 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $13,420,804 $343,461 ($28) $13,764,237 Asset write-offs, impairments, and related charges (credits) $— ($163,464) $— ($163,464) Depreciation, amortization, and decommissioning $1,941,653 $43,446 $— $1,985,099 Interest and investment income (loss) $145,968 ($35,293) ($186,256) ($75,581) Interest expense $750,175 $162,300 ($238) $912,237 Income taxes ($34,263) ($4,715) $— ($38,978) Consolidated net income (loss) $1,398,580 ($115,425) ($186,017) $1,097,138 Total assets $61,399,243 $884,442 ($3,688,494) $58,595,191 Cash paid for long-lived asset additions $5,382,243 $13,884 $— $5,396,127 2021 Utility Parent & Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,251 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $263,625 Depreciation, amortization, and decommissioning $1,823,389 $167,308 $— $1,990,697 Interest and investment income $442,817 $115,273 ($127,624) $430,466 Interest expense $692,004 $142,693 ($3) $834,694 Income taxes $264,209 ($72,835) $— $191,374 Consolidated net income (loss) $1,488,487 ($242,146) ($127,622) $1,118,719 Total assets $59,733,625 $1,718,638 ($1,998,021) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,257 $— $6,422,112 |
Risk Management And Fair Valu_2
Risk Management And Fair Values (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 2022 Assets: Natural gas swaps and options Prepayments and other $13 $— $ 13 Natural gas swaps and options Other deferred debits and other assets $3 $— $ 3 Financial transmission rights Prepayments and other $21 ($2) $ 19 Liabilities: Natural gas swaps and options Other current liabilities $25 $— $ 25 (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2022. Also excludes letters of credit in the amount of $2 million posted as of December 31, 2023 and $3 million posted as of December 31, 2022. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($54) Financial transmission rights Purchased power expense (b) $ 124 2022 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) $ 74 Financial transmission rights Purchased power expense (b) $ 176 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $ 32 Financial transmission rights Purchased power expense (b) $ 179 Electricity swaps and options (c) Other operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options prior to the expiration of the non-utility operations business’ portfolio of derivative instruments in April 2021. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $61 $— $— $61 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 611 1,159 — 1,770 Common trusts (b) 3,070 Securitization recovery trust account 8 — — 8 Storm reserve escrow accounts 323 — — 323 Financial transmission rights — — 21 21 $1,027 $1,159 $21 $5,277 Liabilities: Gas hedge contracts $11 $— $— $11 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $109 $— $— $109 Decommissioning trust funds (a): Equity securities 24 — — 24 Debt securities 534 1,122 — 1,656 Common trusts (b) 2,442 Securitization recovery trust account 13 — — 13 Storm reserve escrow accounts 402 — — 402 Gas hedge contracts 13 3 — 16 Financial transmission rights — — 19 19 $1,095 $1,125 $19 $4,681 Liabilities: Gas hedge contracts $25 $— $— $25 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 16 to the financial statements for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2023, 2022, and 2021: 2023 2022 2021 Financial transmission rights Financial transmission rights Power Contracts Financial transmission rights Balance as of January 1, $19 $4 $38 $9 Total gains (losses) for the period Included in earnings — — (2) — Included in other comprehensive income — — 2 — Included as a regulatory liability/asset 84 175 — 162 Issuances of financial transmission rights 42 16 — 12 Settlements (124) (176) (38) (179) Balance as of December 31, $21 $19 $— $4 |
Entergy Arkansas [Member] | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | Entergy Arkansas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Decommissioning trust funds (a): Equity securities 6.4 — — 6.4 Debt securities 129.9 367.0 — 496.9 Common trusts (b) 910.7 Financial transmission rights — — 6.0 6.0 $139.4 $367.0 $6.0 $1,423.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.4 $— $— $3.4 Decommissioning trust funds (a): Equity securities 4.5 — — 4.5 Debt securities 126.8 343.9 — 470.7 Common trusts (b) 724.7 Financial transmission rights — — 10.3 10.3 $134.7 $343.9 $10.3 $1,213.6 |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2023 $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.3 1.4 0.2 Gains (losses) included as a regulatory liability/asset 0.9 44.8 13.2 5.3 19.4 Settlements (25.8) (60.4) (13.7) (6.4) (17.3) Balance as of December 31, 2023 $6.0 $9.8 $1.4 $1.1 $2.4 The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2022 $2.3 $0.6 $0.3 $0.1 $0.8 Issuances of financial transmission rights 5.4 5.3 0.8 0.8 3.9 Gains (losses) included as a regulatory liability/asset 109.1 49.9 9.9 3.6 1.7 Settlements (106.5) (48.5) (10.4) (3.7) (6.3) Balance as of December 31, 2022 $10.3 $7.3 $0.6 $0.8 $0.1 |
Entergy Louisiana [Member] | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | Entergy Louisiana 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $0.5 $— $— $0.5 Decommissioning trust funds (a): Equity securities 14.6 — — 14.6 Debt securities 271.7 516.4 — 788.1 Common trusts (b) 1,304.7 Storm reserve escrow account 243.8 — — 243.8 Financial transmission rights — — 9.8 9.8 $530.6 $516.4 $9.8 $2,361.5 Liabilities: Gas hedge contracts $0.4 $— $— $0.4 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.3 $— $— $6.3 Decommissioning trust funds (a): Equity securities 16.8 — — 16.8 Debt securities 209.4 515.7 — 725.1 Common trusts (b) 1,037.2 Storm reserve escrow account 293.4 — — 293.4 Gas hedge contracts 13.1 3.4 — 16.5 Financial transmission rights — — 7.3 7.3 $539.0 $519.1 $7.3 $2,102.6 |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2023 $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.3 1.4 0.2 Gains (losses) included as a regulatory liability/asset 0.9 44.8 13.2 5.3 19.4 Settlements (25.8) (60.4) (13.7) (6.4) (17.3) Balance as of December 31, 2023 $6.0 $9.8 $1.4 $1.1 $2.4 The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2022 $2.3 $0.6 $0.3 $0.1 $0.8 Issuances of financial transmission rights 5.4 5.3 0.8 0.8 3.9 Gains (losses) included as a regulatory liability/asset 109.1 49.9 9.9 3.6 1.7 Settlements (106.5) (48.5) (10.4) (3.7) (6.3) Balance as of December 31, 2022 $10.3 $7.3 $0.6 $0.8 $0.1 |
Entergy Mississippi [Member] | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | Entergy Mississippi 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.6 $— $— $6.6 Storm reserve escrow account 0.7 — — 0.7 Financial transmission rights — — 1.4 1.4 $7.3 $— $1.4 $8.7 Liabilities: Gas hedge contracts $10.1 $— $— $10.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $17.0 $— $— $17.0 Storm reserve escrow account 33.5 — — 33.5 Financial transmission rights — — 0.6 0.6 $50.5 $— $0.6 $51.1 Liabilities: Gas hedge contracts $24.0 $— $— $24.0 |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2023 $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.3 1.4 0.2 Gains (losses) included as a regulatory liability/asset 0.9 44.8 13.2 5.3 19.4 Settlements (25.8) (60.4) (13.7) (6.4) (17.3) Balance as of December 31, 2023 $6.0 $9.8 $1.4 $1.1 $2.4 The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2022 $2.3 $0.6 $0.3 $0.1 $0.8 Issuances of financial transmission rights 5.4 5.3 0.8 0.8 3.9 Gains (losses) included as a regulatory liability/asset 109.1 49.9 9.9 3.6 1.7 Settlements (106.5) (48.5) (10.4) (3.7) (6.3) Balance as of December 31, 2022 $10.3 $7.3 $0.6 $0.8 $0.1 |
Entergy New Orleans [Member] | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | Entergy New Orleans 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Securitization recovery trust account $2.4 $— $— $2.4 Storm reserve escrow account 78.7 — — 78.7 Financial transmission rights — — 1.1 1.1 $81.1 $— $1.1 $82.2 Liabilities: Gas hedge contracts $0.6 $— $— $0.6 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $4.4 $— $— $4.4 Securitization recovery trust account 2.2 — — 2.2 Storm reserve escrow account 75.0 — — 75.0 Financial transmission rights — — 0.8 0.8 $81.6 $— $0.8 $82.4 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2023 $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.3 1.4 0.2 Gains (losses) included as a regulatory liability/asset 0.9 44.8 13.2 5.3 19.4 Settlements (25.8) (60.4) (13.7) (6.4) (17.3) Balance as of December 31, 2023 $6.0 $9.8 $1.4 $1.1 $2.4 The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2022 $2.3 $0.6 $0.3 $0.1 $0.8 Issuances of financial transmission rights 5.4 5.3 0.8 0.8 3.9 Gains (losses) included as a regulatory liability/asset 109.1 49.9 9.9 3.6 1.7 Settlements (106.5) (48.5) (10.4) (3.7) (6.3) Balance as of December 31, 2022 $10.3 $7.3 $0.6 $0.8 $0.1 |
Entergy Texas [Member] | |
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block] | The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2023 Assets: Financial transmission rights Prepayments and other $6.0 $— $ 6.0 Entergy Arkansas Financial transmission rights Prepayments and other $9.8 $— $ 9.8 Entergy Louisiana Financial transmission rights Prepayments and other $1.4 $— $ 1.4 Entergy Mississippi Financial transmission rights Prepayments and other $1.1 $— $ 1.1 Entergy New Orleans Financial transmission rights Prepayments and other $2.7 ($0.3) $ 2.4 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.4 $— $ 0.4 Entergy Louisiana Natural gas swaps Other current liabilities $10.1 $— $ 10.1 Entergy Mississippi Natural gas swaps Other current liabilities $0.6 $— $ 0.6 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2022 Assets: Natural gas swaps and options Prepayments and other $13.1 $— $ 13.1 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $3.4 $— $ 3.4 Entergy Louisiana Financial transmission rights Prepayments and other $10.3 $— $ 10.3 Entergy Arkansas Financial transmission rights Prepayments and other $7.7 ($0.4) $ 7.3 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $ 0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.8 $— $ 0.8 Entergy New Orleans Financial transmission rights Prepayments and other $1.2 ($1.1) $ 0.1 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $24.0 $— $ 24.0 Entergy Mississippi Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. |
Derivatives Not Designated as Hedging Instruments [Table Text Block] | The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($8.4) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($42.9) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 25.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 60.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 13.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 6.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 17.3 (b) Entergy Texas 2022 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 21.4 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 53.6 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 106.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 48.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 10.4 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.7 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 6.3 (b) Entergy Texas 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 42.6 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 31.6 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 11.3 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 85.9 (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | Entergy Texas 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $20.5 $— $— $20.5 Securitization recovery trust account 5.2 — — 5.2 Financial transmission rights — — 2.4 2.4 $25.7 $— $2.4 $28.1 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $3.0 $— $— $3.0 Securitization recovery trust account 10.9 — — 10.9 Financial transmission rights — — 0.1 0.1 $13.9 $— $0.1 $14.0 |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Table Text Block] | The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2023 $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.3 1.4 0.2 Gains (losses) included as a regulatory liability/asset 0.9 44.8 13.2 5.3 19.4 Settlements (25.8) (60.4) (13.7) (6.4) (17.3) Balance as of December 31, 2023 $6.0 $9.8 $1.4 $1.1 $2.4 The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2022 $2.3 $0.6 $0.3 $0.1 $0.8 Issuances of financial transmission rights 5.4 5.3 0.8 0.8 3.9 Gains (losses) included as a regulatory liability/asset 109.1 49.9 9.9 3.6 1.7 Settlements (106.5) (48.5) (10.4) (3.7) (6.3) Balance as of December 31, 2022 $10.3 $7.3 $0.6 $0.8 $0.1 |
System Energy [Member] | |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | System Energy 2023 Level 1 Level 2 Level 3 Total (In Millions) Assets: Decommissioning trust funds (a): Equity securities $2.7 $— $— $2.7 Debt securities 209.5 275.7 — 485.2 Common trusts (b) 854.4 $212.2 $275.7 $— $1,342.3 2022 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $2.9 $— $— $2.9 Decommissioning trust funds (a): Equity securities 2.8 — — 2.8 Debt securities 197.5 262.2 — 459.7 Common trusts (b) 680.4 $203.2 $262.2 $— $1,145.8 |
Decommissioning Trust Funds (Ta
Decommissioning Trust Funds (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $1,770 $19 $134 2022 Debt Securities $1,655 $4 $201 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $82 $62 1 year - 5 years 517 520 5 years - 10 years 504 461 10 years - 15 years 121 117 15 years - 20 years 179 161 20 years+ 367 334 Total $1,770 $1,655 |
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block] | The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $134 $6 $840 $63 More than 12 months 999 128 666 138 Total $1,133 $134 $1,506 $201 |
Entergy Arkansas [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $496.9 $2.4 $53.6 2022 Debt Securities $470.7 $0.2 $69.3 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $45.3 $21.2 1 year - 5 years 132.2 159.7 5 years - 10 years 205.7 191.7 10 years - 15 years 39.9 38.0 15 years - 20 years 49.6 42.6 20 years+ 24.2 17.5 Total $496.9 $470.7 |
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block] | The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $22.5 $0.4 $197.6 $18.8 More than 12 months 403.4 53.2 260.1 50.5 Total $425.9 $53.6 $457.7 $69.3 |
Entergy Louisiana [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $788.1 $11.7 $37.4 2022 Debt Securities $725.1 $3.5 $67.5 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $31.4 $33.6 1 year - 5 years 181.6 159.1 5 years - 10 years 170.0 161.7 10 years - 15 years 70.2 67.1 15 years - 20 years 90.2 83.3 20 years+ 244.7 220.3 Total $788.1 $725.1 |
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block] | The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $69.8 $0.9 $409.9 $24.6 More than 12 months 356.1 36.5 207.5 42.9 Total $425.9 $37.4 $617.4 $67.5 |
System Energy [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of December 31, 2023 and 2022 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2023 Debt Securities $485.2 $4.5 $42.5 2022 Debt Securities $459.7 $0.7 $63.7 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2023 and 2022 are as follows: 2023 2022 (In Millions) Less than 1 year $5.3 $6.8 1 year - 5 years 203.4 201.7 5 years - 10 years 128.6 107.1 10 years - 15 years 10.7 11.7 15 years - 20 years 38.8 35.0 20 years+ 98.4 97.4 Total $485.2 $459.7 |
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block] | The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2023 and 2022: December 31, 2023 December 31, 2022 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $42.1 $4.5 $231.9 $19.2 More than 12 months 239.1 38.0 198.0 44.5 Total $281.2 $42.5 $429.9 $63.7 |
Transactions With Affiliates (T
Transactions With Affiliates (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Entergy Arkansas [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Louisiana [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Mississippi [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy New Orleans [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Entergy Texas [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
System Energy [Member] | |
Schedule of Related Party Transactions [Table Text Block] | The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $125.2 $317.6 $1.0 $— $0.7 $588.4 2022 $127.5 $354.0 $1.0 $— $18.9 $658.8 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $585.8 $719.8 $345.2 $302.5 $316.8 $179.0 2022 $617.4 $770.2 $356.1 $341.7 $321.4 $215.0 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2023 $0.7 $303.2 $0.2 $1.0 $1.8 $0.6 2022 $0.1 $186.1 $0.1 $0.1 $0.3 $0.3 2021 $— $127.6 $— $— $— $— |
Revenue Recognition Revenue R_2
Revenue Recognition Revenue Recognition (Tables) | 12 Months Ended |
Dec. 31, 2023 | |
Disaggregation of Revenue [Table Text Block] | Entergy’s total revenues for the years ended December 31, 2023, 2022 and 2021 are as follows: 2023 2022 2021 (In Thousands) Utility: Residential $4,552,804 $4,640,039 $3,981,846 Commercial 2,997,888 3,087,675 2,610,207 Industrial 3,170,090 3,716,058 2,942,370 Governmental 270,640 286,605 245,685 Total billed retail 10,991,422 11,730,377 9,780,108 Sales for resale (a) 366,348 858,743 601,895 Other electric revenues (b) 352,056 481,256 375,312 Revenues from contracts with customers 11,709,826 13,070,376 10,757,315 Other Utility revenues (c) 132,628 116,469 116,680 Electric revenues 11,842,454 13,186,845 10,873,995 Natural gas revenues 180,490 233,920 170,610 Other revenues (d) 124,468 343,472 698,291 Total operating revenues $12,147,412 $13,764,237 $11,742,896 |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Entergy Arkansas [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Entergy Louisiana [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Entergy Mississippi [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Entergy New Orleans [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Entergy Texas [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the year ended December 31, 2023 were as follows: 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $996,760 $1,576,129 $748,428 $317,188 $914,299 Commercial 584,304 1,104,509 604,343 235,193 469,539 Industrial 635,472 1,720,298 217,916 31,831 564,573 Governmental 20,409 83,736 60,477 77,152 28,866 Total billed retail 2,236,945 4,484,672 1,631,164 661,364 1,977,277 Sales for resale (a) 269,648 357,900 104,058 63,360 10,497 Other electric revenues (b) 121,425 151,252 49,752 (992) 35,988 Revenues from contracts with customers 2,628,018 4,993,824 1,784,974 723,732 2,023,762 Other revenues (c) 18,378 79,415 17,559 14,242 4,824 Electric revenues 2,646,396 5,073,239 1,802,533 737,974 2,028,586 Natural gas revenues — 74,531 — 105,959 — Total operating revenues $2,646,396 $5,147,770 $1,802,533 $843,933 $2,028,586 The Utility operating companies’ total revenues for the year ended December 31, 2022 were as follows: 2022 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $946,719 $1,775,552 $651,455 $335,471 $930,842 Commercial 530,512 1,274,665 508,996 256,963 516,539 Industrial 559,147 2,275,978 182,270 36,970 661,693 Governmental 20,186 94,910 52,861 87,514 31,134 Total billed retail 2,056,564 5,421,105 1,395,582 716,918 2,140,208 Sales for resale (a) 443,685 555,640 167,867 120,851 66,782 Other electric revenues (b) 159,178 204,878 51,554 13,637 57,379 Revenues from contracts with customers 2,659,427 6,181,623 1,615,003 851,406 2,264,369 Other revenues (c) 13,767 65,310 9,231 3,842 24,536 Electric revenues 2,673,194 6,246,933 1,624,234 855,248 2,288,905 Natural gas revenues — 91,835 — 142,085 — Total operating revenues $2,673,194 $6,338,768 $1,624,234 $997,333 $2,288,905 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas revenues — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 (a) Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators. (c) Other Utility revenues include the equity component of carrying costs related to securitization, settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. (d) Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, operation and management services fees, and amortization of a below-market power purchase agreement. |
Allowance For Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2023 and 2022. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 Provisions 38.7 9.4 13.9 7.3 3.4 4.7 Write-offs (83.1) (20.6) (31.3) (10.4) (10.7) (10.1) Recoveries 39.4 11.9 15.9 3.9 3.2 4.5 Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Provisions (a) 40.6 14.9 10.7 3.2 7.7 4.1 Write-offs (112.5) (31.2) (45.1) (12.1) (13.5) (10.6) Recoveries 34.2 9.7 12.8 4.2 4.4 3.1 Balance as of December 31, 2022 $30.9 $6.5 $7.6 $2.5 $11.9 $2.4 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of ($6.4) million for Entergy, $6.4 million for Entergy Arkansas, ($8.5) million for Entergy Louisiana, ($3.0) million for Entergy New Orleans, and ($1.3) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for information on regulatory assets recorded as a result of the COVID-19 pandemic and orders issued by retail regulators. |
Summary Of Significant Accoun_4
Summary Of Significant Accounting Policies (Narrative) (Details) $ in Thousands | 1 Months Ended | 3 Months Ended | 12 Months Ended | |||
Mar. 31, 2018 $ / kWh | Mar. 31, 2017 $ / kWh | Sep. 30, 2023 USD ($) | Dec. 31, 2023 USD ($) $ / kWh shares | Dec. 31, 2022 USD ($) shares | Dec. 31, 2021 USD ($) shares | |
Income Tax Expense (Benefit) | $ (690,535) | $ (38,978) | $ 191,374 | |||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 193,000 | $ 208,000 | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | shares | 1,179,962 | 931,453 | 1,013,320 | |||
Asset Impairment Charges | $ 42,679 | $ (163,464) | $ 263,625 | |||
Regulatory Liability, Noncurrent | $ 3,116,926 | $ 2,324,590 | ||||
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service | 2.90% | 2.80% | 2.70% | |||
Equity Distribution Program [Member] | ||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | shares | 1,762,709 | 1,158,917 | 1,158,917 | |||
Utility [Member] | ||||||
Income Tax Expense (Benefit) | $ (374,847) | $ (34,263) | $ 264,209 | |||
Asset Impairment Charges | 79,962 | 0 | 0 | |||
Entergy Louisiana [Member] | ||||||
Income Tax Expense (Benefit) | $ (205,781) | $ (162,853) | $ 120,409 | |||
Depreciation Rate On Average Depreciable Property | 2.60% | 2.40% | 2.40% | |||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 187,200 | $ 202,200 | ||||
Percentage Interest in River Bend | 30% | |||||
Percentage portion of River Bend plant costs, generation, revenues, and expenses operated under the Louisiana retail deregulated portion of River Bend | 15% | |||||
Rate At Which Electricity Sold To Retail Customers | $ / kWh | 0.046 | |||||
Limit Above Which Incremental Revenue Shared Between Customers and Shareholders | $ / kWh | 0.046 | |||||
Regulatory Liability, Noncurrent | $ 1,407,689 | 1,037,962 | ||||
Entergy Texas [Member] | ||||||
Income Tax Expense (Benefit) | $ 62,872 | $ 50,621 | $ 25,526 | |||
Depreciation Rate On Average Depreciable Property | 4% | 3.10% | 3.20% | |||
Regulatory Liability, Noncurrent | $ 43,013 | $ 45,247 | ||||
Entergy Arkansas [Member] | ||||||
Income Tax Expense (Benefit) | $ (99,210) | $ 80,896 | $ 75,195 | |||
Depreciation Rate On Average Depreciable Property | 2.70% | 2.70% | 2.70% | |||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 100 | $ 100 | ||||
Rate At Which Electricity Sold To Retail Customers | $ / kWh | 0.01547 | 0.01164 | ||||
Asset Impairment Charges | 78,434 | 0 | $ 0 | |||
Regulatory Liability, Noncurrent | 759,181 | 475,758 | ||||
Entergy Arkansas [Member] | Utility [Member] | ||||||
Asset Impairment Charges | $ 78,000 | |||||
Entergy Mississippi [Member] | ||||||
Income Tax Expense (Benefit) | $ 54,364 | $ 54,864 | $ 45,323 | |||
Depreciation Rate On Average Depreciable Property | 3.60% | 3.60% | 3.60% | |||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 500 | $ 500 | ||||
Regulatory Liability, Noncurrent | 33,696 | 79,865 | ||||
Entergy New Orleans [Member] | ||||||
Income Tax Expense (Benefit) | $ (189,973) | $ 24,277 | $ 5,936 | |||
Depreciation Rate On Average Depreciable Property | 3.30% | 3.20% | 3.20% | |||
Regulatory Liability, Noncurrent | $ 90,434 | $ 20,735 | ||||
System Energy [Member] | ||||||
Income Tax Expense (Benefit) | $ 32,032 | $ (92,828) | $ (1,977) | |||
Depreciation Rate On Average Depreciable Property | 1.60% | 2% | 1.90% | |||
Regulatory Liability, Noncurrent | $ 782,912 | $ 665,024 |
Summary Of Significant Accoun_5
Summary Of Significant Accounting Policies (Schedule Of Net Property, Plant, And Equipment) (Details) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 USD ($) MW | Dec. 31, 2022 USD ($) | |
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | $ 9,927,000 | $ 9,590,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 12,927,000 | 12,363,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 66,850,474 | 64,646,911 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 2,109,703 | 1,844,171 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 708,000 | 582,000 |
Public Utilities, Property, Plant and Equipment, Net | 43,834,329 | 42,477,124 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 193,000 | 208,000 |
Independence Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 7.18% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 21,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 15,000 | |
Roy S Nelson Unit Six [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 514 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 10.90% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 120,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 74,000 | |
Roy S Nelson Unit Six Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 5.97% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 3,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 1,000 | |
Independence Unit Two [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 842 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 14.37% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 79,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 59,000 | |
Entergy Arkansas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 2,102,000 | 2,086,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 3,395,000 | 2,981,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 14,821,814 | 14,077,844 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 340,601 | 417,244 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 214,000 | 176,000 |
Public Utilities, Property, Plant and Equipment, Net | 9,373,934 | 8,941,958 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 100 | 100 |
Entergy Arkansas [Member] | Independence Unit One [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 824 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 31.50% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 145,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 108,000 | |
Entergy Arkansas [Member] | Independence Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 15.75% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 42,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 31,000 | |
Entergy Arkansas [Member] | White Bluff Units One And Two [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 1,244 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 57% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 593,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 404,000 | |
Entergy Arkansas [Member] | Ouachita Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 66.67% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 173,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 159,000 | |
Entergy Arkansas [Member] | Union Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 29,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 12,000 | |
Entergy Louisiana [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 4,283,000 | 4,055,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 4,371,000 | 4,827,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 27,800,467 | 27,498,136 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 592,803 | 736,969 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 333,000 | 213,000 |
Public Utilities, Property, Plant and Equipment, Net | 18,471,693 | 18,661,823 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 187,200 | 202,200 |
Entergy Louisiana [Member] | Ouachita Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 33.33% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 91,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 79,000 | |
Entergy Louisiana [Member] | Union Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 50% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 59,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 14,000 | |
Entergy Louisiana [Member] | Roy S Nelson Unit Six [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 514 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 40.25% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 299,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 224,000 | |
Entergy Louisiana [Member] | Roy S Nelson Unit Six Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 22.04% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 22,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 11,000 | |
Entergy Louisiana [Member] | Big Cajun Two Unit Three [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 548 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 24.15% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 149,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 136,000 | |
Entergy Louisiana [Member] | Big Cajun 2 Unit 3 Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 8.05% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 5,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 3,000 | |
Entergy Louisiana [Member] | Acadia Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 50% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 22,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 3,000 | |
Entergy Mississippi [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 1,483,000 | 1,435,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 2,272,000 | 2,035,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 7,455,145 | 7,079,849 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 139,635 | 170,191 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 0 | 0 |
Public Utilities, Property, Plant and Equipment, Net | 5,248,453 | 4,985,254 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | $ 500 | 500 |
Entergy Mississippi [Member] | Independence Units One And Two And Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 1,666 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 293,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 182,000 | |
Entergy New Orleans [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 143,000 | 131,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 692,000 | 625,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 2,046,928 | 1,934,837 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 25,424 | 39,607 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 0 | 0 |
Public Utilities, Property, Plant and Equipment, Net | $ 1,615,526 | 1,556,472 |
Entergy New Orleans [Member] | Union Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 30,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 10,000 | |
Entergy Texas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 1,882,000 | 1,846,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 2,197,000 | 1,895,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 7,931,340 | 7,409,461 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 857,707 | 339,139 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 0 | 0 |
Public Utilities, Property, Plant and Equipment, Net | $ 6,425,128 | 5,613,200 |
Entergy Texas [Member] | Roy S Nelson Unit Six [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 514 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 29.75% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 211,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 141,000 | |
Entergy Texas [Member] | Roy S Nelson Unit Six Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 16.30% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 8,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 4,000 | |
Entergy Texas [Member] | Big Cajun Two Unit Three [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Capability | MW | 548 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 17.85% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 112,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 101,000 | |
Entergy Texas [Member] | Big Cajun 2 Unit 3 Common Facilities [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Coal | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 5.95% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 4,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 2,000 | |
Entergy Texas [Member] | Montgomery County Power Station [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Gas | |
Jointly Owned Utility Plant, Capability | MW | 915 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 92.44% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 745,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 54,000 | |
System Energy [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Transmission | 32,000 | 34,000 |
Public Utilities, Property, Plant and Equipment, Distribution | 0 | 0 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 5,495,728 | 5,425,449 |
Public Utilities, Property, Plant and Equipment, Construction Work in Progress | 130,866 | 102,987 |
Public Utilities, Property, Plant And Equipment, Nuclear Fuel | 161,000 | 193,000 |
Public Utilities, Property, Plant and Equipment, Net | $ 2,293,950 | 2,309,183 |
System Energy [Member] | Grand Gulf Unit One [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Jointly Owned Utility Plant, Fuel Type | Nuclear | |
Jointly Owned Utility Plant, Capability | MW | 1,383 | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 90% | |
Jointly Owned Utility Plant, Net Ownership Amount | $ 5,499,000 | |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | 3,494,000 | |
Nuclear Plant [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 7,944,000 | 7,936,000 |
Nuclear Plant [Member] | Entergy Arkansas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 1,859,000 | 1,858,000 |
Nuclear Plant [Member] | Entergy Louisiana [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 4,153,000 | 4,116,000 |
Nuclear Plant [Member] | Entergy Mississippi [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 0 | 0 |
Nuclear Plant [Member] | Entergy New Orleans [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 0 | 0 |
Nuclear Plant [Member] | Entergy Texas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 0 | 0 |
Nuclear Plant [Member] | System Energy [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 1,932,000 | 1,962,000 |
Other Plant In Service [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 7,045,000 | 7,256,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 3,173,000 | 2,906,000 |
Other Plant In Service [Member] | Entergy Arkansas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 892,000 | 916,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 571,000 | 508,000 |
Other Plant In Service [Member] | Entergy Louisiana [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 3,583,000 | 3,652,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 1,156,000 | 1,062,000 |
Other Plant In Service [Member] | Entergy Mississippi [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 958,000 | 988,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 395,000 | 357,000 |
Other Plant In Service [Member] | Entergy New Orleans [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 386,000 | 403,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 370,000 | 357,000 |
Other Plant In Service [Member] | Entergy Texas [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 1,177,000 | 1,244,000 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | 311,000 | 289,000 |
Other Plant In Service [Member] | System Energy [Member] | ||
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Property, Plant and Equipment, Generation or Processing | 0 | 0 |
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment | $ 38,000 | $ 17,000 |
Summary Of Significant Accoun_6
Summary Of Significant Accounting Policies (Schedule Of Depreciation Rates On Average Depreciable Property) (Details) | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Entergy Arkansas [Member] | |||
Depreciation Rate On Average Depreciable Property | 2.70% | 2.70% | 2.70% |
Entergy Louisiana [Member] | |||
Depreciation Rate On Average Depreciable Property | 2.60% | 2.40% | 2.40% |
Entergy Mississippi [Member] | |||
Depreciation Rate On Average Depreciable Property | 3.60% | 3.60% | 3.60% |
Entergy New Orleans [Member] | |||
Depreciation Rate On Average Depreciable Property | 3.30% | 3.20% | 3.20% |
Entergy Texas [Member] | |||
Depreciation Rate On Average Depreciable Property | 4% | 3.10% | 3.20% |
System Energy [Member] | |||
Depreciation Rate On Average Depreciable Property | 1.60% | 2% | 1.90% |
Summary Of Significant Accoun_7
Summary Of Significant Accounting Policies (Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations) (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Independence Unit One [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 31.50% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 145 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 108 |
Independence Common Facilities [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 7.18% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 21 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 15 |
Independence Common Facilities [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 15.75% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 42 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 31 |
White Bluff Units One And Two [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 57% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 593 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 404 |
Ouachita Common Facilities [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 66.67% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 173 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 159 |
Ouachita Common Facilities [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 33.33% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 91 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 79 |
Roy S Nelson Unit Six [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 10.90% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 120 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 74 |
Roy S Nelson Unit Six [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 40.25% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 299 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 224 |
Roy S Nelson Unit Six [Member] | Entergy Texas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 29.75% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 211 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 141 |
Roy S Nelson Unit Six Common Facilities [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 5.97% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 3 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 1 |
Roy S Nelson Unit Six Common Facilities [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 22.04% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 22 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 11 |
Roy S Nelson Unit Six Common Facilities [Member] | Entergy Texas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 16.30% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 8 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 4 |
Big Cajun Two Unit Three [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 24.15% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 149 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 136 |
Big Cajun Two Unit Three [Member] | Entergy Texas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 17.85% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 112 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 101 |
Big Cajun 2 Unit 3 Common Facilities [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 8.05% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 5 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 3 |
Big Cajun 2 Unit 3 Common Facilities [Member] | Entergy Texas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 5.95% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 4 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 2 |
Acadia Common Facilities [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 50% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 22 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 3 |
Independence Units One And Two And Common Facilities [Member] | Entergy Mississippi [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 293 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 182 |
Grand Gulf Unit One [Member] | System Energy [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Nuclear |
Jointly Owned Utility Plant, Proportionate Ownership Share | 90% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 5,499 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 3,494 |
Independence Unit Two [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Coal |
Jointly Owned Utility Plant, Proportionate Ownership Share | 14.37% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 79 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 59 |
Ouachita Units One And Two [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 100% |
Ouachita Unit Three [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 100% |
Union Common Facilities [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 29 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 12 |
Union Common Facilities [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 50% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 59 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 14 |
Union Common Facilities [Member] | Entergy New Orleans [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Fuel Type | Gas |
Jointly Owned Utility Plant, Proportionate Ownership Share | 25% |
Jointly Owned Utility Plant, Net Ownership Amount | $ 30 |
Jointly Owned Utility Plant, Ownership Amount of Plant Accumulated Depreciation | $ 10 |
Union Unit 1 [Member] | Entergy New Orleans [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 100% |
Union Unit 2 [Member] | Entergy Arkansas [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 100% |
Union Units 3 and 4 [Member] | Entergy Louisiana [Member] | |
Jointly Owned Utility Plant Interests [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 100% |
Summary Of Significant Accoun_8
Summary Of Significant Accounting Policies (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Earnings Per Share, Basic [Abstract] | |||
Net Income (Loss) Available to Common Stockholders, Basic | $ 2,356,536 | $ 1,103,166 | $ 1,118,492 |
Weighted Average Number of Shares Outstanding, Basic | 211,569,931 | 204,450,354 | 200,941,511 |
Earnings Per Share, Basic | $ 11.14 | $ 5.40 | $ 5.57 |
Weighted Average Number of Shares Outstanding, Diluted, Adjustment [Abstract] | |||
Weighted Average Number of Shares Outstanding, Diluted | 212,376,495 | 205,547,578 | 201,873,024 |
Earnings Per Share, Diluted | $ 11.10 | $ 5.37 | $ 5.54 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | $ 2,362,310 | $ 1,097,138 | $ 1,118,719 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | $ 5,774 | $ (6,028) | $ 227 |
Employee Stock Option | |||
Weighted Average Number of Shares Outstanding, Diluted, Adjustment [Abstract] | |||
Incremental Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangements | 300,000 | 400,000 | 400,000 |
Average Dilutive Effect Of Stock Options Per Share | $ (0.01) | $ (0.01) | $ (0.01) |
Restricted Stock Units (RSUs) [Member] | |||
Weighted Average Number of Shares Outstanding, Diluted, Adjustment [Abstract] | |||
Average Dilutive Effect Of Restricted Stock Shares | 500,000 | 500,000 | 600,000 |
Average Dilutive Effect Of Restricted Stock Per Share | $ (0.03) | $ (0.02) | $ (0.02) |
Forward Contracts [Member] | |||
Weighted Average Number of Shares Outstanding, Diluted, Adjustment [Abstract] | |||
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements | 0 | 100,000 | 0 |
Average Dilutive Effect Of Equity Forwards | $ 0 | $ 0 | $ 0 |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative) (Details) | 1 Months Ended | 2 Months Ended | 3 Months Ended | 6 Months Ended | 8 Months Ended | 9 Months Ended | 10 Months Ended | 11 Months Ended | 12 Months Ended | 13 Months Ended | 15 Months Ended | 20 Months Ended | 24 Months Ended | 36 Months Ended | 213 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Nov. 01, 2023 | Oct. 26, 2021 USD ($) | Jan. 01, 2018 USD ($) | Jan. 31, 2024 USD ($) | Dec. 31, 2023 USD ($) | Nov. 30, 2023 USD ($) | Oct. 31, 2023 USD ($) | Sep. 30, 2023 USD ($) | Aug. 31, 2023 USD ($) | Jul. 31, 2023 USD ($) | Jun. 30, 2023 USD ($) $ / unit | May 31, 2023 USD ($) | Apr. 30, 2023 USD ($) | Mar. 31, 2023 USD ($) | Jan. 31, 2023 USD ($) | Dec. 31, 2022 USD ($) | Nov. 30, 2022 USD ($) | Oct. 31, 2022 USD ($) | Sep. 30, 2022 USD ($) | Jul. 31, 2022 USD ($) | Jun. 30, 2022 USD ($) | May 31, 2022 USD ($) | Apr. 30, 2022 USD ($) | Mar. 31, 2022 USD ($) | Feb. 28, 2022 USD ($) | Jan. 31, 2022 USD ($) | Nov. 30, 2021 USD ($) | Oct. 31, 2021 USD ($) | Aug. 31, 2021 USD ($) | Jul. 31, 2021 USD ($) | Jun. 30, 2021 USD ($) | May 31, 2021 | Mar. 31, 2021 USD ($) | Feb. 28, 2021 USD ($) | Dec. 31, 2020 USD ($) | Nov. 30, 2020 USD ($) | Oct. 31, 2020 USD ($) | Sep. 30, 2020 USD ($) | Jul. 31, 2020 USD ($) | Jun. 30, 2020 | May 31, 2020 USD ($) | Apr. 30, 2020 USD ($) | Feb. 29, 2020 | Sep. 30, 2019 | Aug. 31, 2019 USD ($) | Jul. 31, 2019 USD ($) | Jun. 30, 2019 | May 31, 2019 USD ($) | Mar. 31, 2019 USD ($) | Jan. 31, 2019 | Dec. 31, 2018 USD ($) | Oct. 31, 2018 USD ($) | Aug. 31, 2018 USD ($) | Jul. 31, 2018 USD ($) | May 31, 2018 USD ($) | Mar. 31, 2018 USD ($) $ / kWh | Feb. 28, 2018 USD ($) | Mar. 31, 2017 $ / kWh | Jan. 31, 2017 | Apr. 30, 2016 | Jan. 31, 2014 USD ($) | Aug. 31, 2020 USD ($) | Dec. 31, 2023 USD ($) | Sep. 30, 2023 USD ($) | Jun. 30, 2023 USD ($) | Sep. 30, 2022 USD ($) | Dec. 31, 2021 USD ($) | Aug. 31, 2020 USD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2020 USD ($) | Jun. 30, 2021 USD ($) | Jul. 31, 2021 USD ($) | Dec. 31, 2024 USD ($) | Mar. 31, 2024 USD ($) | Dec. 31, 2023 USD ($) $ / kWh | Mar. 31, 2023 USD ($) | Dec. 31, 2022 USD ($) | Mar. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | Mar. 31, 2021 USD ($) | Dec. 31, 2020 USD ($) | Dec. 31, 2019 USD ($) | Dec. 31, 2018 USD ($) | Dec. 31, 2017 USD ($) | Jun. 30, 2024 USD ($) | Apr. 23, 2018 | Dec. 31, 2021 USD ($) | Aug. 31, 2024 USD ($) | Aug. 31, 2024 USD ($) | Mar. 31, 2022 USD ($) | Sep. 30, 2021 USD ($) | Feb. 01, 2023 USD ($) | Oct. 31, 2019 USD ($) | Mar. 31, 2016 USD ($) | |
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | $ 169,967,000 | $ 710,401,000 | $ 169,967,000 | $ 710,401,000 | $ 169,967,000 | $ 710,401,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 5,669,404,000 | 6,036,397,000 | 5,669,404,000 | 6,036,397,000 | 5,669,404,000 | 6,036,397,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 3,116,926,000 | 2,324,590,000 | 3,116,926,000 | 2,324,590,000 | 3,116,926,000 | 2,324,590,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | (138,469,000) | 669,403,000 | $ 111,628,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | (690,535,000) | (38,978,000) | 191,374,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Asset Impairment Charges | 42,679,000 | (163,464,000) | 263,625,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | 463,805,000 | (266,559,000) | 43,631,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | (435,877,000) | (576,859,000) | 536,707,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Rate Increase Included in Formula Rate Plan | $ 4,800,000 | $ 103,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan increase excluding Tax Cuts and Jobs Act Credits | $ 98,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned Return on Common Equity Resulting From Revenue-Neutral Realignments to Other Recovery Mechanisms | 8.16% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned Return on Common Equity Excluding Realignments | 9.88% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 10.61% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | 24,800,000 | 159,183,000 | 24,800,000 | 159,183,000 | 24,800,000 | 159,183,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 1,648,852,000 | 2,056,179,000 | 1,648,852,000 | 2,056,179,000 | 1,648,852,000 | 2,056,179,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.80% | 9.66% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 1,407,689,000 | 1,037,962,000 | 1,407,689,000 | 1,037,962,000 | $ 1,407,689,000 | 1,037,962,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 118,700,000 | $ 63,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Rate At Which Electricity Sold To Retail Customers | $ / kWh | 0.046 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue decrease | $ 17,600,000 | $ 8,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Monthly regulatory liability established to reflect tax benefits already included in retail rates | $ 9,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected increase in revenue requirement | $ 108,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Bandwidth around midpoint of return on equity | 5,000% | 6,000% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fuel Costs | $ 225,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interest income excluded in 2019 FRP filing | $ 251,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Asset | 192,900,000 | 327,300,000 | 192,900,000 | 327,300,000 | $ 192,900,000 | 327,300,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | 41,209,000 | 148,871,000 | 38,245,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LURC's beneficial interest in the storm trust | $ 31,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | (205,781,000) | (162,853,000) | 120,409,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | $ 59,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | 225,645,000 | (4,783,000) | (16,478,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | (407,327,000) | (720,487,000) | 1,050,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Winter Storm Uri [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fuel Costs | $ 166,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | 0 | 143,211,000 | 0 | 143,211,000 | 0 | 143,211,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected under-recovery Energy Cost Recovery Rider | 200,000,000 | 200,000,000 | 200,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 579,076,000 | 519,460,000 | 579,076,000 | 519,460,000 | 579,076,000 | 519,460,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 6.67% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 33,696,000 | 79,865,000 | 33,696,000 | 79,865,000 | 33,696,000 | 79,865,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 39,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Withdrawal from storm reserves | 34,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Asset | 143,200,000 | $ 291,700,000 | $ 100,000,000 | $ 121,900,000 | 143,200,000 | 143,200,000 | 121,900,000 | $ 121,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | (111,376,000) | 38,017,000 | 5,913,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
MPSC settlement refund | $ 235,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Liability | (130,600,000) | (130,600,000) | (130,600,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | 54,364,000 | 54,864,000 | 45,323,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 36,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | (59,513,000) | 20,165,000 | 21,930,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | 59,616,000 | 57,028,000 | (4,909,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | 6,148,000 | 10,153,000 | 6,148,000 | 10,153,000 | 6,148,000 | 10,153,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 182,367,000 | 202,112,000 | 182,367,000 | 202,112,000 | 182,367,000 | 202,112,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 90,434,000 | 20,735,000 | 90,434,000 | 20,735,000 | 90,434,000 | 20,735,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Benefit to electric customers related to reduction in income tax expense under Tax Act | $ 8,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Benefit to gas customers related to reduction in income tax expense under Tax Act | $ 1,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Withdrawal from storm reserves | $ 44,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Asset | 10,200,000 | 14,200,000 | 10,200,000 | 14,200,000 | 10,200,000 | 14,200,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | 69,211,000 | 19,596,000 | 13,177,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | (189,973,000) | 24,277,000 | 5,936,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 7,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | 66,022,000 | (8,639,000) | 4,985,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | (19,745,000) | (46,505,000) | (18,173,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | 139,019,000 | 258,115,000 | 139,019,000 | 258,115,000 | 139,019,000 | 258,115,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 596,606,000 | 578,682,000 | 596,606,000 | 578,682,000 | 596,606,000 | 578,682,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 43,013,000 | 45,247,000 | 43,013,000 | 45,247,000 | 43,013,000 | 45,247,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Return to customers of unprotected excess accumulated deferred income taxes | $ 185,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Refund due customers resulting from lower federal income tax rate | 25,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Return to customers of protected excess accumulated deferred income taxes | $ 242,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Asset | 139,000,000 | 258,100,000 | 139,000,000 | 258,100,000 | 139,000,000 | 258,100,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | 7,324,000 | 49,175,000 | 59,581,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | 62,872,000 | 50,621,000 | 25,526,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 33,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | (20,122,000) | (30,499,000) | (28,747,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | 17,924,000 | 157,349,000 | $ (103,380,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Incremental Fuel and Replacement Energy Costs | $ 65,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | 0 | 139,739,000 | 0 | 139,739,000 | 0 | 139,739,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 1,885,361,000 | 1,810,281,000 | 1,885,361,000 | 1,810,281,000 | 1,885,361,000 | $ 1,810,281,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.65% | 9.75% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 759,181,000 | 475,758,000 | 759,181,000 | 475,758,000 | 759,181,000 | $ 475,758,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Portion of Approved Revenue Requirement Increase Subject to Possible Future Adjustment and Refund to Customers | $ 45,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
ALJ Recommended Percentage By Which Payments Be Reduced | 20% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Liability Recorded Related to Estimated Payments Due Utility Operating Companies | $ 35,000,000 | $ 87,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs | $ 31,000,000 | $ 75,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Rate At Which Electricity Sold To Retail Customers | $ / kWh | 0.01547 | 0.01164 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase in Rate At Which Electricity Sold To Retail Customers | $ / kWh | 0.01882 | 0.01547 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tax benefits to customers resulting from tax adjustment rider | $ 5,600,000 | $ 467,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Refund to customers, plus interest, associated with recalculated bandwidth remedy | $ 13,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested revenue increase resulting from settlement agreement | $ 68,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduced proposed revenue increase resulting from new methodology | 72,600,000 | $ 1,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider Rate Per kWh | $ 0.016390 | $ 0.00959 | $ 0.01052 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduced proposed increase in revenue requirement to comply with annual revenue constraint | $ 72,100,000 | $ 72,400,000 | 74,300,000 | $ 74,300,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Annual revenue constraint per rate class percentage | 400% | 400% | 400% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Asset | 208,600,000 | 208,600,000 | 208,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | (87,409,000) | (89,418,000) | (31,501,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested Energy Cost Recovery Rider Rate Per kWh | 0.01785 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Payments for Legal Settlements | 135,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost - Net Liability | (88,300,000) | (88,300,000) | (88,300,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | (99,210,000) | 80,896,000 | 75,195,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Asset Impairment Charges | 78,434,000 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | 240,762,000 | (264,054,000) | 21,066,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | $ 6,197,000 | 120,603,000 | (142,706,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Entergy Arkansas [Member] | February 2021 Winter Storms [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Cost | $ 32,000,000 | $ 32,000,000 | $ 32,000,000 | 32,000,000 | $ 32,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.65% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Incremental Fuel and Replacement Energy Costs | $ 360,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 10.94% | 10.94% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recommended adjustment to earned return on equity | 9.32% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Percent Interest in Grand Gulf | 90% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Annual renewal lease payments on Grand Gulf Sale-Leaseback | $ 17,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback | $ 512,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 446,360,000 | 415,121,000 | 446,360,000 | 415,121,000 | $ 446,360,000 | 415,121,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 52% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 782,912,000 | 665,024,000 | 782,912,000 | 665,024,000 | 782,912,000 | 665,024,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC staff argued over-recovery in depreciation expense for capital additions | $ 32,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
First refund period requested authorized rate of return - LPSC | 7.97% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
First refund period requested authorized rate of return - MPSC and APSC | 9.24% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
First refund period requested authorized rate of return - FERC | 9.49% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Second refund period requested authorized rate of return - MPSC and APSC | 9.15% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Second refund period requested authorized rate of return - LPSC | 7.78% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Second refund period requested authorized rate of return - FERC | 9.09% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
First refund period requested authorized rate of return | 10.12% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Second refund period requested authorized rate of return | 9.44% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interest Portion of LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback | 310,000,000 | 310,000,000 | 310,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Remaining NBV of Leased Assets | $ 70,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Refund of Lease Payments | $ 17,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Future nuclear decommissioning costs allowed by the IRS in cost of goods sold | $ 102,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Percent of requested deduction allowed by IRS of uncertain decommissioning tax postion | 10% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional unprotected excess ADIT related to uncertain decommissioning tax deduction | $ 147,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proposed credit of excess accumulated deferred income taxes resulting from decommissioning uncertain tax position | 17,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
One-time accumulated deferred income tax credit | $ 25,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accumulated deferred income tax credits to customers | $ 3,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | (57,429,000) | 503,162,000 | 26,214,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Estimated Return On Equity Complaint Refund | 41,000,000 | 41,000,000 | 41,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Return On Equity Complaint - Estimated Annual Rate Reduction | 25,000,000 | 25,000,000 | 25,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Pre-authorization amount for capital improvement projects | $ 125,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Potential settlement refund | $ 353,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Previously recorded liability related to applicable litigation | 37,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory charge related to System Energy settlement | 551,000,000 | 40,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory charge related to System Energy settlement - net of tax | 413,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability related to potential settlement refund | 178,000,000 | $ 588,000,000 | 588,000,000 | 178,000,000 | 588,000,000 | 178,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | 32,032,000 | (92,828,000) | (1,977,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Estimated Litigation Liability | 37,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | 11,009,000 | 21,252,000 | 40,884,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | 31,239,000 | 19,575,000 | (143,417,000) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
System Energy [Member] | First Refund Period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LPSC requested authorized return on equity for System Energy in return on equity proceeding | 8.44% | 7.81% | 7.81% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding | 8.41% | 8.24% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC requested authorized return on equity for System Energy in return on equity proceeding | 9.89% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding | 8.26% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal | 9.22% | 9.40% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested return on equity based on alternative methodology | 10.26% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
System Energy [Member] | Second refund period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LPSC requested authorized return on equity for System Energy in return on equity proceeding | 7.89% | 7.97% | 7.97% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding | 8.01% | 8.41% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public utilities requested return on equity percentage, median 2nd refund period | 9.65% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public utilities requested return on equity percentage, midpoint 2nd refund period | 9.74% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Modified public utilities requested return on equity percentage based on benchmarks, median 2nd refund period | 9.91% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Modified public utilities requested return on equity percentage based on benchmarks, midpoint 2nd refund period | 10.30% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding | 8.32% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal | 8.66% | 9.63% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Minimum [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recommended adjustment to earned return on equity | 8.37% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Minimum [Member] | System Energy [Member] | First Refund Period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.10% | 10.10% | 8.57% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Minimum [Member] | System Energy [Member] | Second refund period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 8.28% | 10.32% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Maximum [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recommended adjustment to earned return on equity | 8.67% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Percent Equity in Proposed Common Equity Ratio | 37% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Percent Debt in Proposed Common Equity Ratio | 63% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LPSC Argued Equity Capital Structure, Percentage | 49% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC and MPSC Argued Equity Capital Structure, Percentage | 35.98% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
APSC and MPSC Alternative Argued Equity Capital Structure, Percentage | 46.75% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC Percent Equity in Proposed Common Equity Ratio | 46.74% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC Percent Debt in Proposed Common Equity Ratio | 53.26% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
ALJ Recommended Equity Capital Structure, Percentage | 48.15% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Maximum [Member] | System Energy [Member] | First Refund Period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.70% | 9.52% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Maximum [Member] | System Energy [Member] | Second refund period [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.11% | 10.69% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Opportunity Sales [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 131,800,000 | 131,800,000 | 131,800,000 | 131,800,000 | 131,800,000 | 131,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Opportunity Sales [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 131,800,000 | 131,800,000 | 116,000,000 | 131,800,000 | 131,800,000 | 131,800,000 | 131,800,000 | $ 116,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Storm Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 536,900,000 | 841,300,000 | 536,900,000 | 841,300,000 | 536,900,000 | 841,300,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Storm Costs [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 202,600,000 | 472,800,000 | 202,600,000 | 472,800,000 | 202,600,000 | 472,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Storm Costs [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 3,900,000 | 17,200,000 | 3,900,000 | 17,200,000 | 3,900,000 | 17,200,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Storm Costs [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 297,300,000 | 315,400,000 | 297,300,000 | 315,400,000 | 297,300,000 | 315,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Storm Costs [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 33,100,000 | 35,900,000 | 33,100,000 | 35,900,000 | 33,100,000 | 35,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan historical year rate adjustment [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 0 | 18,200,000 | 0 | 18,200,000 | 0 | 18,200,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan historical year rate adjustment [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 0 | 18,200,000 | 0 | 19,000,000 | 18,200,000 | 0 | 18,200,000 | $ 19,000,000 | 19,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred COVID-19 costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 118,000,000 | 120,900,000 | 118,000,000 | 120,900,000 | 118,000,000 | 120,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred COVID-19 costs [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 47,800,000 | 47,800,000 | 47,800,000 | 47,800,000 | 47,800,000 | 47,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of long-term debt proposed to be used to generate earnings to reduce certain regulatory assets | $ 1,600,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred COVID-19 costs [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 13,000,000 | 13,900,000 | 13,000,000 | 13,900,000 | 13,000,000 | 13,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred COVID-19 costs [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 8,400,000 | 10,400,000 | 8,400,000 | 10,400,000 | 8,400,000 | 10,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred COVID-19 costs [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 39,000,000 | 39,000,000 | 39,000,000 | 39,000,000 | 39,000,000 | 39,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 143,900,000 | 157,400,000 | 143,900,000 | 157,400,000 | 143,900,000 | 157,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 85,900,000 | 81,800,000 | 85,900,000 | 81,800,000 | 85,900,000 | 81,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 11,000,000 | 24,800,000 | 11,000,000 | 24,800,000 | 11,000,000 | 24,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 24,000,000 | 25,200,000 | 24,000,000 | 25,200,000 | 24,000,000 | 25,200,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 8,600,000 | 14,400,000 | 8,600,000 | 14,400,000 | 8,600,000 | 14,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 17,100,000 | 15,900,000 | 17,100,000 | 15,900,000 | 17,100,000 | 15,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred Fuel Costs [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Asset Impairment Charges | $ 68,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Excess accumulated deferred income taxes as a result of the Tac Cuts and Jobs Act [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Assets and Liabilities | $ 106,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Subsequent Event [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.50% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution recovery mechanism - amount per year | $ 225,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue increase limit - exclusive of riders | $ 70,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferral of expenditures on vegetation management | $ 7,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Subsequent Event [Member] | Minimum [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Subsequent Event [Member] | Maximum [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 10% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Certain receipts under affiliated PPAs [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 21,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Rate Case Settlement Relate Back [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 10,300,000 | 0 | 10,300,000 | 0 | 10,300,000 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Refund from System Energy settlement with the APSC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 93,000,000 | 0 | 93,000,000 | 0 | 93,000,000 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Refund from System Energy settlement with the APSC [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 93,000,000 | 0 | 93,000,000 | 0 | 93,000,000 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 177,900,000 | 249,800,000 | 177,900,000 | 249,800,000 | 177,900,000 | 249,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 103,500,000 | 103,500,000 | 103,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Short-term financing interest earnings [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | 36,800,000 | 0 | 36,800,000 | 0 | $ 36,800,000 | $ 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Long-Term Contract for Purchase of Electric Power, Share of Plant Output Being Purchased | 40% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.65% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 52% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 11.50% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability related to potential settlement refund | 588,000,000 | 588,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf [Member] | Entergy Arkansas and Entergy Mississippi | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Long-Term Contract for Purchase of Electric Power, Share of Plant Output Being Purchased | 65% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf [Member] | Refund from System Energy settlement with the APSC [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Noncurrent | $ 93,000,000 | $ 93,000,000 | $ 93,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Montgomery County Power Station [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment, Useful Life | 40 years | 38 years | 38 years | 38 years | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Percentage of Undivided Ownership Interest | 7.56% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 66,100,000 | 51,000,000 | $ 2,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue increase resulting from incremental revenue | $ 31,600,000 | $ 15,100,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 2,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 40,200,000 | 26,300,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue increase resulting from incremental revenue | $ 6,800,000 | $ 13,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2020 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 8.45% | 8.45% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 14,200,000 | $ 63,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 64,900,000 | 50,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2020 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | Legacy Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 32,800,000 | 27,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2020 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | Legacy Entergy Gulf States Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 32,100,000 | $ 23,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2020 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 8.22% | 9.07% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 88,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Provision for Rate Refund | $ 43,500,000 | $ 43,500,000 | $ 43,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduced proposed revenue increase resulting from new methodology | 43,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | 44,500,000 | $ 39,800,000 | $ 64,300,000 | $ 23,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Generation Cost Recovery Rider [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 5,700,000 | $ 5,000,000 | $ 88,300,000 | 88,300,000 | $ 91,000,000 | 92,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue increase resulting from incremental revenue | 4,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Generation Cost Recovery Rider [Member] | Montgomery County Power Station [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 86,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 8.33% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 65,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue increase | 152,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | Legacy Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue increase | 86,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | Legacy Entergy Gulf States Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue increase | 66,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 6.12% | 6.69% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 48,200,000 | $ 95,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Demand side management costs | 3,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan revenue increase including demand side management costs | 48,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interim rate adjustment | 1,700,000 | 1,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total interim rate adjustments | 18,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | 17,500,000 | $ 16,800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Formula rate plan increase related to COVID-19 non-bad debt expense | 3,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | $ 19,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Cap on retail revenues | 2% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.35% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 6.26% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 64,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 49,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Customer Refund Liability, Current | 17,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 7.65% | 7.92% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 82,200,000 | 108,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | $ 89,200,000 | $ 19,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Increase in Revenue Requirement | 62,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Maximum [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 44,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Percentage | 4% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 22,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 40,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 34,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional revenue increase due to previously approved amounts | 5,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proposed formula rate plan rate mitigation through offsets to regulatory liabilities | 10,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2021 Formula Rate Plan Filing [Member] | Natural Gas, US Regulated [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 18,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 14,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional revenue increase due to previously approved amounts | $ 300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proposed formula rate plan rate mitigation through offsets to regulatory liabilities | 4,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
System Energy Formula Rate Annual Protocols Formal Challenge [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Payments for Legal Settlements | $ 235,000,000 | $ 235,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of refunds ordered in a given year | $ 80 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of retail customers receiving bill credit | 460,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
MPSC settlement refund | 198,300,000 | 36,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
System Energy Formula Rate Annual Protocols Formal Challenge [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Estimated Financial Impact | 53,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Portion of estimated financial impact attributable to sale-leaseback payments | $ 17,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Base Rate Case [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 54,000,000 | 50,700,000 | $ 131,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset | 4,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 24,100,000 | 24,600,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Base Rate Case [Member] | Other Regulatory Assets (Liabilities) [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 14,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Base Rate Case [Member] | 2022 Rate Case Settlement Relate Back [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability | $ 10,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fuel Reconciliation [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments | 1,700,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred fuel under-recovery balance, including interest, for reconciliation period | 103,100,000 | 103,100,000 | 103,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Margins from off-system sales made during the reconciliation period | $ 9,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Deferred fuel under-recovery balance, including interest, for reconciliation period per settlement | 99,700,000 | $ 99,700,000 | $ 99,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interim Fuel Surcharge [Member] | Entergy Texas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 51,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 26,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.35% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 500,000 | $ 25,600,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Customer Refund Liability, Current | $ 8,900,000 | 8,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested reduction to formula rate plan revenues resulting from alleged errors | 8,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proposed formula rate plan rate mitigation through offsets to regulatory liabilities | 12,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 7.29% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 130,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | $ 49,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction in recovery due to excess accumulated deferred income taxes from reductions in state income tax rates | 24,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recovery related to the resolution of the 2016 and 2017 IRS audits from previous tax positions that are no longer uncertain | 34,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Maximum [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 400% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 88,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Adjusted Public Utilities Requested Rate Increase Decrease Amount Per Service Commission | $ 87,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Storm Costs [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Subsequent Event [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 8.11% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | $ 80,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 7.34% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 17,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 10,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional revenue increase due to previously approved amounts | $ 3,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Natural Gas, US Regulated [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Oil and Gas, Average Production Cost Per Unit | $ / unit | 4.50 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Filing [Member] | Natural Gas, US Regulated [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 3.52% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 8,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 6,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Look-back Filing [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | $ 800,000 | $ 800,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 19,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 27,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on rate base | 6.10% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested refund for true-up of demand-side management costs | $ 1,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Look-back Filing [Member] | Maximum [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Percentage | 2% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Look-back Filing [Member] | Formula Rate Plan Historical Year Rate Adjustment Member [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 18,200,000 | 18,200,000 | 18,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Look-back Filing [Member] | Subsequent Event [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 19,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Annual power management rider [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | 4,100,000 | $ 4,100,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in over (under) Energy Recovery | $ 51,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Annual power management rider [Member] | Subsequent Event [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in over (under) Energy Recovery | $ 47,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grid modernization rider [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset, Noncurrent | $ 4,300,000 | $ 4,300,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Request for Extension and Modification of Formula Rate Plan [Member] | Maximum [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 55% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total Refunds Received | $ 27,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total Refunds Received | 34,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total Refunds Received | 41,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 41,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
New Orleans City Council Witness Recommended Refund | $ 98,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
New Orleans City Council Recommended Hypothetical Equity Ratio Prospectively | 48.15% | 48.15% | 48.15% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of refunds ordered in a given year | 50,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC Staff Recommended Refund | $ 106,600,000 | $ 84,100,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LPSC estimated refund without interest | 286,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
New Orleans City Council proposed refunds related to the money pool | 51,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction in the revenue requirement - money pool included in short-term debt | 1,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction in revenue requirement - money pool credited through UPSA | 1,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction in revenue requirement for every $50M in refunds | 1,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Potential settlement refund | 18,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 103,500,000 | 103,500,000 | 103,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total Refunds Paid | 103,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disallowance of future sale-leaseback renewal costs recovery | 11,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Calculated refund of sale-leaseback renewal rental costs, including interest | 89,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Calculated net refund for excess depreciation expense | 13,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Collective refunds and interest sought by public utilities | $ 700,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC ALJ initial decision recommended refunds | $ 116,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interest component of FERC ALJ initial decision recommended refunds | $ 152,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FERC ALJ initial decision modification to cash working capital allowance | $ 36,400,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Prudence Complaint [Member] | System Energy, Entergy Services, and Entergy Operations [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Loss Contingency, Damages Sought, Value | $ 1,000,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Depreciation Amendment Proceeding [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction to depreciation expense resulting from differences in depreciation rates | $ 41,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Pension Costs Amendment Proceeding [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 8,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 8.33% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 70,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 85,200,000 | 85,200,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | $ 65,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Prospective return on common equity opportunity | 8.38% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution recovery mechanism revenue requirement | $ 6,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 5.99% | 6.70% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 48,600,000 | $ 69,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Interim fuel refund for cumulative over-recovery | 14,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 34,300,000 | 34,500,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Regulatory Charges (Credits) Net | 22,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Cap on retail revenues | 2% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.35% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earned return on common equity | 6.88% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 42,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 24,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Customer Refund Liability, Current | 13,900,000 | $ 13,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proposed formula rate plan rate mitigation through offsets to regulatory liabilities | 17,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 7.40% | 8.38% | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 102,800,000 | 119,900,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduced proposed increase in revenue requirement to comply with annual revenue constraint | $ 79,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected Revenue Deficiency | $ 87,700,000 | $ 104,800,000 | $ 15,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional increase in revenue requirement | $ 79,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Maximum [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 4,900,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Maximum [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 48,600,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Percentage | 4% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 24,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 34,100,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 18,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional revenue increase due to previously approved amounts | 4,700,000 | 4,700,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2022 Formula Rate Plan Filing [Member] | Natural Gas, US Regulated [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 3,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 1,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Rate Case [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected increase in revenue requirement | $ 430,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Prospective return on common equity opportunity | 10.50% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
One-time customer credits | $ 17,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2023 Formula Rate Plan Extention Proposal [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Projected increase in revenue requirement | $ 173,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Prospective return on common equity opportunity | 10% | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
One-time customer credits | $ 17,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in over (under) Energy Recovery | $ 80,600,000 | $ 24,400,000 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider Rate Per kWh | $ 0.01639 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider [Member] | Subsequent Event [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in over (under) Energy Recovery | $ 142,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider [Member] | Subsequent Event [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Energy Cost Recovery Rider Rate Per kWh | $ 0.01883 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Requested Energy Cost Recovery Rider Rate Per kWh | $ 0.01883 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Payments for Legal Settlements | 18,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Allocated sale-leaseback annual renewal costs | 5,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Payments for Legal Settlements | 22,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Cumulative proceeds awarded from legal settlements | 142,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Payments for Legal Settlements | $ 103,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Expense (Benefit) | 13,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Recalculated Payments for Legal Settlements | $ 35,700,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 67,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Waived proceed from legal settlement resulting from compliance filing | 27,300,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction to accumulated deferred income tax asset | 94,000,000 | 94,000,000 | 94,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction to accumulated deferred income tax regulatory liability | 25,000,000 | 25,000,000 | 25,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reduction to depreciation expense and related accumulated depreciation | 33,000,000 | 33,000,000 | 33,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Calculation of additional refunds resulting form decommissioning tax position issue, presented in compliance report | $ 493,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Other Regulatory Assets | $ 40,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Sale-leaseback and depreciation-related refunds [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset | $ 40,500,000 | $ 40,500,000 | 40,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Unit Power Sales Agreement Complaint [Member] | System Energy [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Sale-leaseback regulatory liability reduction | $ 56,000,000 | $ 56,000,000 | $ 56,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Grand Gulf [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Proceeds from Legal Settlements | 49,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Cumulative proceeds awarded from legal settlements | $ 142,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Test Years 2017-2021 Formula Rate Plan Filings [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
One-time customer credits | 5,800,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Test Years 2017-2021 Formula Rate Plan Filings [Member] | Associated with Late Fees from 2016 Flood [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Assets and Liabilities | 6,200,000 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Test Years 2017-2021 Formula Rate Plan Filings [Member] | Excess accumulated deferred income taxes as a result of the Tac Cuts and Jobs Act [Member] | Entergy Louisiana [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Assets and Liabilities | $ 105,600,000 |
Rate and Regulatory Matters (St
Rate and Regulatory Matters (Storm Narrative) (Details) | 1 Months Ended | 3 Months Ended | 6 Months Ended | 9 Months Ended | 12 Months Ended | ||||||||||||||||||||||||||||||||||||||
Jan. 01, 2018 USD ($) | Dec. 31, 2023 USD ($) | Aug. 31, 2023 USD ($) | Mar. 31, 2023 USD ($) shares | Dec. 31, 2022 USD ($) | Oct. 31, 2022 USD ($) | Sep. 30, 2022 USD ($) | Aug. 31, 2022 USD ($) | Jun. 30, 2022 USD ($) | May 31, 2022 USD ($) shares | Apr. 30, 2022 USD ($) | Feb. 28, 2022 USD ($) | Dec. 31, 2021 USD ($) | Sep. 30, 2021 USD ($) | Aug. 31, 2021 | May 31, 2021 USD ($) | Apr. 30, 2021 USD ($) | Mar. 31, 2021 USD ($) | Nov. 30, 2020 USD ($) | May 31, 2019 USD ($) | May 31, 2015 USD ($) | Aug. 31, 2014 USD ($) $ / unit shares | Jun. 30, 2014 USD ($) | Jul. 31, 2010 USD ($) $ / unit shares | Aug. 31, 2008 USD ($) $ / unit shares | Jul. 31, 2008 USD ($) shares | Mar. 31, 2023 USD ($) shares | Jun. 30, 2023 USD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2023 USD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2017 USD ($) | Jan. 31, 2023 USD ($) | Mar. 31, 2022 USD ($) | Jan. 31, 2022 USD ($) | Feb. 29, 2012 shares | Apr. 30, 2010 USD ($) | Aug. 26, 2008 USD ($) | Jul. 29, 2008 USD ($) | Apr. 30, 2008 USD ($) | |
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | $ 4,273,297,000 | $ 6,019,835,000 | $ 8,308,427,000 | ||||||||||||||||||||||||||||||||||||||||
Storm Reserve Escrow Account | $ 323,206,000 | $ 401,955,000 | $ 401,955,000 | $ 323,206,000 | 401,955,000 | ||||||||||||||||||||||||||||||||||||||
Reduction of income tax expense | $ 129,000,000 | $ 283,000,000 | |||||||||||||||||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | |||||||||||||||||||||||||||||||||||||||
4.00% Series mortgage bonds due July 2022 [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||||||||||||||||||||||||||||||||||||||||||
Repayments of First Mortgage Bond | $ 650,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Mortgage Bonds Zero Point Six Two Percent Series Due November 2023 [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 0.62% | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | $ 1,410,893,000 | 2,942,771,000 | 3,769,166,000 | ||||||||||||||||||||||||||||||||||||||||
Amount transfer from restricted escrow account as storm damage reserve | $ 257,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs | $ 2,640,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Storm Reserve Escrow Account | 243,819,000 | 293,406,000 | $ 290,000,000 | $ 290,000,000 | 293,406,000 | 243,819,000 | 293,406,000 | ||||||||||||||||||||||||||||||||||||
Aggregate principal amount of system restoration bonds authorization requested | 3,186,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Reclassification from utility plant to other regulatory assets | $ 1,942,000,000 | ||||||||||||||||||||||||||||||||||||||||||
LCDA issuance of bonds under Act 293 financing | $ 3,194,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in majority owned subsidiary | shares | 14,576,757.48 | 31,635,718.7221 | 14,576,757.48 | ||||||||||||||||||||||||||||||||||||||||
LURC's percentage of annual dividends | 1% | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana's percentage of annual dividends | 99% | 99% | |||||||||||||||||||||||||||||||||||||||||
Preferred Stock, Dividend Rate, Percentage | 7.50% | 7% | |||||||||||||||||||||||||||||||||||||||||
Preferred Stock, Liquidation Preference, Value | $ 100 | $ 100 | $ 100 | ||||||||||||||||||||||||||||||||||||||||
Proceeds from Contributed Capital | 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Proceeds from capital contribution used to fund Hurricane Ida escrow | 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Funds withdrawn from Hurricane Ida escrow and applied to restoration costs | 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Restricted storm escrow funds | 290,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Reduction of income tax expense | 133,000,000 | 290,000,000 | |||||||||||||||||||||||||||||||||||||||||
Regulatory charge recorded as a result of reduction in income tax expense | 103,000,000 | 224,000,000 | 103,000,000 | ||||||||||||||||||||||||||||||||||||||||
Regulatory charge recorded as a result of reduction in income tax expense, net of tax | $ 76,000,000 | 165,000,000 | $ 76,000,000 | ||||||||||||||||||||||||||||||||||||||||
LURC's beneficial interest in the storm trust, percentage | 1% | 1% | 1% | ||||||||||||||||||||||||||||||||||||||||
Reduction to income tax expense - net of provision for uncertain tax positions | $ 133,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Reduction to income tax expense - net, offset by other tax charges | 129,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | ||||||||||||||||||||||||||||||||||||||||||
Minimum customer benefits | $ 30,800,000 | ||||||||||||||||||||||||||||||||||||||||||
Annual customer credits | $ 6,200,000 | ||||||||||||||||||||||||||||||||||||||||||
LCDA issuance of bonds under Louisiana Act 55 financing | $ 314,850,000 | ||||||||||||||||||||||||||||||||||||||||||
Bond proceeds loaned by LCDA to LURC under Louisiana Act 55 financing | 309,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount transfered to restricted escrow account as storm damage reserve | 16,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Bond proceeds transfered to company under Louisiana Act 55 financing | $ 293,000,000 | ||||||||||||||||||||||||||||||||||||||||||
LURC's beneficial interest in the storm trust | 31,600,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Entergy Finance Company [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
LURC's beneficial interest in the storm trust | 14,600,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Unsecured Term Loan due June 2023 [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Repayments of Unsecured Debt | 1,200,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Six Two Percent Series Due November 2023 [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Repayments of First Mortgage Bond | 435,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | 2,060,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Deferred Storm and Property Reserve Deficiency, Noncurrent | 1,680,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Non-capital storm costs | 380,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs | 32,000,000 | 2,100,000,000 | 2,110,000,000 | ||||||||||||||||||||||||||||||||||||||||
Storm carrying costs | 51,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Carrying costs associated with storm restoration costs | 3,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Aggregate principal amount of system restoration bond authorization approved | $ 1,491,000,000 | $ 1,491,000,000 | |||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri [Member] | Storm Costs [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset | $ 180,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricane Ida [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | $ 2,640,000,000 | 2,540,000,000 | |||||||||||||||||||||||||||||||||||||||||
Deferred Storm and Property Reserve Deficiency, Noncurrent | 1,960,000,000 | 1,000,000,000 | $ 1,000,000,000 | 1,000,000,000 | |||||||||||||||||||||||||||||||||||||||
Non-capital storm costs | 586,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs | 2,600,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Aggregate principal amount of system restoration bonds authorization requested | 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Carrying costs associated with storm restoration costs | $ 59,100,000 | 57,000,000 | |||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricane Katrina and Hurricane Rita [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Minimum amount of benefits committed to pass on to the customers | $ 40,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Prospective Annual rate reductions for five years | $ 8,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Reduction to Louisiana Act 55 financing savings obligation regulatory liability due to Tax Cuts and Jobs Act | $ 22,300,000 | ||||||||||||||||||||||||||||||||||||||||||
Issuance of bond by government authority | $ 278,400,000 | $ 687,700,000 | |||||||||||||||||||||||||||||||||||||||||
Proceed from loan by government authority to corporation | $ 274,700,000 | $ 679,000,000 | |||||||||||||||||||||||||||||||||||||||||
Amount transfer to restricted escrow account as storm damage reserve by corporation | 87,000,000 | 152,000,000 | |||||||||||||||||||||||||||||||||||||||||
Amount Transferred to subsidiary | 187,700,000 | 527,000,000 | |||||||||||||||||||||||||||||||||||||||||
Amount used to acquire membership interest units in wholly owned Subsidiary | $ 189,400,000 | $ 545,000,000 | |||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in wholly owned Subsidiary | shares | 1,893,918.39 | 5,449,861.85 | |||||||||||||||||||||||||||||||||||||||||
Annual distribution rate | 10% | 10% | |||||||||||||||||||||||||||||||||||||||||
Liquidation price per unit | $ / unit | 100 | ||||||||||||||||||||||||||||||||||||||||||
Net worth required under terms of membership interest | $ 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount withdrawn from restricted escrow account as approved by units of wholly owned subsidiary | $ 1,700,000 | $ 17,800,000 | |||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricane Gustav And Ike [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Minimum amount of benefits committed to pass on to the customers | $ 43,300,000 | ||||||||||||||||||||||||||||||||||||||||||
Prospective Annual rate reductions for five years | $ 8,700,000 | ||||||||||||||||||||||||||||||||||||||||||
Reduction to Louisiana Act 55 financing savings obligation regulatory liability due to Tax Cuts and Jobs Act | $ 2,700,000 | ||||||||||||||||||||||||||||||||||||||||||
Issuance of bond by government authority | $ 713,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Proceed from loan by government authority to corporation | 702,700,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount transfer to restricted escrow account as storm damage reserve by corporation | 290,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount Transferred to subsidiary | 412,700,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount used to acquire membership interest units in wholly owned Subsidiary | $ 412,700,000 | ||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in wholly owned Subsidiary | shares | 4,126,940.15 | ||||||||||||||||||||||||||||||||||||||||||
Annual distribution rate | 9% | ||||||||||||||||||||||||||||||||||||||||||
Liquidation price per unit | $ / unit | 100 | ||||||||||||||||||||||||||||||||||||||||||
Net worth required under terms of membership interest | $ 1,000,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Louisiana [Member] | Hurricanes Ida, Laura, Delta, Zeta, and Winter Storm Uri [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | 2,570,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Aggregate principal amount of system restoration bonds authorization requested | 1,657,000,000 | 1,657,000,000 | 1,657,000,000 | $ 1,491,000,000 | |||||||||||||||||||||||||||||||||||||||
Carrying costs associated with storm restoration costs | 59,200,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Finance Company, LLC [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
proceeds from issuance of preferred interest distributed from EFC to EHC | 1,400,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Proceeds from issuance of preferred interest distributed from EFC to ETR | $ 1,700,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Holdings Company LLC [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in wholly owned Subsidiary | shares | 2,935,152.69 | ||||||||||||||||||||||||||||||||||||||||||
Annual distribution rate | 7.50% | ||||||||||||||||||||||||||||||||||||||||||
Liquidation price per unit | $ / unit | 100 | ||||||||||||||||||||||||||||||||||||||||||
Net worth required under terms of membership interest | $ 1,750,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Holdings Company LLC [Member] | Hurricane Katrina and Hurricane Rita [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in majority owned subsidiary | shares | 6,843,780.24 | ||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units sold in majority owned subsidiary | shares | 500,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Holdings Company LLC [Member] | Hurricane Gustav And Ike [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in majority owned subsidiary | shares | 4,126,940.15 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Holdings Company LLC [Member] | Hurricane Isaac [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Class preferred non voting membership interest units acquired in majority owned subsidiary | shares | 2,935,152.69 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Mississippi [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | 396,833,000 | 249,266,000 | 398,284,000 | ||||||||||||||||||||||||||||||||||||||||
Storm Reserve Escrow Account | 656,000 | 33,549,000 | 33,549,000 | 656,000 | 33,549,000 | ||||||||||||||||||||||||||||||||||||||
Monthly storm damage provision | 1,750,000 | ||||||||||||||||||||||||||||||||||||||||||
Authorized Storm Damage Reserve Balance | 15,000,000 | 15,000,000 | |||||||||||||||||||||||||||||||||||||||||
Balance At Which Storm Damage Accrual Will Return To Current Level | $ 10,000,000 | 10,000,000 | |||||||||||||||||||||||||||||||||||||||||
Withdrawal from storm reserves | 34,500,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy New Orleans [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | 14,610,000 | 0 | 183,403,000 | ||||||||||||||||||||||||||||||||||||||||
Storm Reserve Escrow Account | $ 78,731,000 | 75,000,000 | 75,000,000 | 78,731,000 | 75,000,000 | ||||||||||||||||||||||||||||||||||||||
Withdrawal from storm reserves | $ 44,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Replenishment amount for storm reserve spending | $ 63,900,000 | ||||||||||||||||||||||||||||||||||||||||||
Up front financing costs associated with securitization | $ 3,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy New Orleans [Member] | Hurricane Ida [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | $ 170,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Carrying costs associated with storm restoration costs | 9,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Withdrawal from storm reserves | 125,000,000 | 39,000,000 | |||||||||||||||||||||||||||||||||||||||||
Estimated costs included in filing for total restoration costs for repair and replacement of electrical system | 11,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Prudently incurred storm restoration costs | $ 164,100,000 | ||||||||||||||||||||||||||||||||||||||||||
Outages from storm | 100% | ||||||||||||||||||||||||||||||||||||||||||
Reduction to requested total restoration costs for repair and replacement of electrical system | $ 46,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Replenishment amount for storm reserve spending | $ 150,000,000 | ||||||||||||||||||||||||||||||||||||||||||
initial funding for storm reserve spending | $ 75,000,000 | ||||||||||||||||||||||||||||||||||||||||||
storm restoration costs approved for securitization | $ 206,000,000 | ||||||||||||||||||||||||||||||||||||||||||
storm securitization costs approved for securitization allocated to Hurricane Ida | $ 125,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Carrying costs associated with storm restoration costs deemed prudently incurred | 7,500,000 | ||||||||||||||||||||||||||||||||||||||||||
Storm costs deemed previously recovered through base rates | 1,200,000 | ||||||||||||||||||||||||||||||||||||||||||
Credits available to be applied to future storm costs | $ 900,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy New Orleans [Member] | Hurricane Zeta [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | $ 36,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Estimated costs included in filing for total restoration costs for repair and replacement of electrical system | $ 7,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Prudently incurred storm restoration costs | $ 33,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Excess withdrawn replacement reserve escrow | $ 7,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy New Orleans [Member] | Hurricane [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Issuance of bond by government authority | 209,300,000 | $ 209,300,000 | 209,300,000 | ||||||||||||||||||||||||||||||||||||||||
Amount transfer to restricted escrow account as storm damage reserve by corporation | 200,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Proceeds from Debt, Net of Issuance Costs | 201,800,000 | ||||||||||||||||||||||||||||||||||||||||||
Up front financing costs associated with securitization | $ 1,800,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Texas [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | $ 344,895,000 | $ 606,168,000 | $ 127,931,000 | ||||||||||||||||||||||||||||||||||||||||
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Total Restoration Costs For Repair and Replacement of Electrical System | $ 243,000,000 | 250,000,000 | |||||||||||||||||||||||||||||||||||||||||
Deferred Storm and Property Reserve Deficiency, Noncurrent | 200,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Non-capital storm costs | 50,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Reclassification from utility plant to other regulatory assets | $ 153,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount to be charged to storm reserve and excluded from securitization | 4,300,000 | ||||||||||||||||||||||||||||||||||||||||||
Amount to be excluded from securitization related to no particular issue | 5,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Attestation costs to be excluded from securitization | $ 300,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri [Member] | Aggregate Senior secured restoration bonds (securitization bonds) [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Proceeds from Issuance of Debt | $ 290,850,000 | ||||||||||||||||||||||||||||||||||||||||||
Entergy Texas [Member] | Hurricane Harvey [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset | $ 13,300,000 | ||||||||||||||||||||||||||||||||||||||||||
Remaining restoration costs for repair and replacement of electrical system; previously-approved | $ 13,000,000 | $ 13,000,000 | |||||||||||||||||||||||||||||||||||||||||
Mortgage Bonds Zero Point Six Two Percent Series Due November 2023 [Member] | Entergy Louisiana [Member] | |||||||||||||||||||||||||||||||||||||||||||
Regulatory Asset [Line Items] | |||||||||||||||||||||||||||||||||||||||||||
Long-term debt | $ 1,100,000,000 | ||||||||||||||||||||||||||||||||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 0.62% |
Rate And Regulatory Matters (De
Rate And Regulatory Matters (Details Of Other Regulatory Assets Included In Entergy Corporation And Subsidiaries) (Details) - USD ($) | Dec. 31, 2023 | Dec. 31, 2022 | Jul. 31, 2022 | Jan. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2018 |
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | $ 5,669,404,000 | $ 6,036,397,000 | ||||
Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 1,885,361,000 | 1,810,281,000 | ||||
Deferred Fuel Cost - Net Asset | 208,600,000 | |||||
Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 1,648,852,000 | 2,056,179,000 | ||||
Deferred Fuel Cost - Net Asset | 192,900,000 | 327,300,000 | ||||
Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 579,076,000 | 519,460,000 | ||||
Deferred Fuel Cost - Net Asset | 143,200,000 | $ 291,700,000 | $ 100,000,000 | $ 121,900,000 | ||
Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 182,367,000 | 202,112,000 | ||||
Deferred Fuel Cost - Net Asset | 10,200,000 | 14,200,000 | ||||
Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 596,606,000 | 578,682,000 | ||||
Deferred Fuel Cost - Net Asset | 139,000,000 | 258,100,000 | ||||
System Energy [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 446,360,000 | 415,121,000 | ||||
Asset Retirement Obligation Costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 1,285,000,000 | 1,103,200,000 | ||||
Asset Retirement Obligation Costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 639,100,000 | 562,700,000 | ||||
Asset Retirement Obligation Costs [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 408,700,000 | 346,300,000 | ||||
Asset Retirement Obligation Costs [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 6,800,000 | 6,300,000 | ||||
Asset Retirement Obligation Costs [Member] | System Energy [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 222,000,000 | 186,100,000 | ||||
Pension And Postretirement Costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 1,655,500,000 | 1,968,500,000 | ||||
Pension And Postretirement Costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 536,600,000 | 597,600,000 | ||||
Pension And Postretirement Costs [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 412,000,000 | 481,700,000 | ||||
Pension And Postretirement Costs [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 127,600,000 | 148,800,000 | ||||
Pension And Postretirement Costs [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 41,400,000 | 51,400,000 | ||||
Pension And Postretirement Costs [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 85,600,000 | 100,500,000 | ||||
Pension And Postretirement Costs [Member] | System Energy [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 121,600,000 | 133,900,000 | ||||
Storm Costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 536,900,000 | 841,300,000 | ||||
Storm Costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 33,100,000 | 35,900,000 | ||||
Storm Costs [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 202,600,000 | 472,800,000 | ||||
Storm Costs [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 3,900,000 | 17,200,000 | ||||
Storm Costs [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 297,300,000 | 315,400,000 | ||||
Removal Costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 1,010,700,000 | 1,058,900,000 | ||||
Removal Costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 319,700,000 | 267,100,000 | ||||
Regulatory Asset | 319,700,000 | 267,100,000 | ||||
Removal Costs [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 262,300,000 | 418,800,000 | ||||
Regulatory Asset | 262,300,000 | 418,800,000 | ||||
Removal Costs [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 188,000,000 | 159,400,000 | ||||
Regulatory Asset | 188,000,000 | 159,400,000 | ||||
Removal Costs [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 61,100,000 | 56,300,000 | ||||
Regulatory Asset | 61,100,000 | 56,300,000 | ||||
Removal Costs [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 77,500,000 | 62,900,000 | ||||
Regulatory Asset | 77,500,000 | 62,900,000 | ||||
Removal Costs [Member] | System Energy [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 102,100,000 | 94,400,000 | ||||
Regulatory Asset | 102,100,000 | 94,400,000 | ||||
Attorney General Litigation Costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 10,900,000 | 15,700,000 | ||||
Attorney General Litigation Costs [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 10,900,000 | 15,700,000 | ||||
Neches and Sabine Costs [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 11,600,000 | 14,000,000 | ||||
Regulatory Clause Revenues, under-Recovered [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 248,600,000 | 160,000,000 | ||||
Regulatory Clause Revenues, under-Recovered [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 24,900,000 | 26,400,000 | ||||
Regulatory Clause Revenues, under-Recovered [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 192,800,000 | 111,100,000 | ||||
Loss on Reacquired Debt [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 63,100,000 | 68,400,000 | ||||
Loss on Reacquired Debt [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 19,900,000 | 21,400,000 | ||||
Loss on Reacquired Debt [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 23,400,000 | 25,100,000 | ||||
Loss on Reacquired Debt [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 10,000,000 | 10,900,000 | ||||
Loss on Reacquired Debt [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 800,000 | 1,200,000 | ||||
Loss on Reacquired Debt [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 8,300,000 | 9,100,000 | ||||
Loss on Reacquired Debt [Member] | System Energy [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 700,000 | 700,000 | ||||
ANO Fukushima and Flood Barrier costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 3,800,000 | 5,600,000 | ||||
Opportunity Sales [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 131,800,000 | 131,800,000 | ||||
Opportunity Sales [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 131,800,000 | 131,800,000 | $ 116,000,000 | |||
Retired electric meters [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 36,300,000 | 39,800,000 | ||||
Retired electric meters [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 18,800,000 | 21,400,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 143,900,000 | 157,400,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 17,100,000 | 15,900,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 85,900,000 | 81,800,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 11,000,000 | 24,800,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 24,000,000 | 25,200,000 | ||||
Other Regulatory Assets (Liabilities) [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 8,600,000 | 14,400,000 | ||||
Retired electric and gas meters [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 153,800,000 | 166,800,000 | ||||
Retired electric and gas meters [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 83,200,000 | 88,000,000 | ||||
Retired electric and gas meters [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 15,500,000 | 17,600,000 | ||||
Deferred COVID-19 costs [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 118,000,000 | 120,900,000 | ||||
Deferred COVID-19 costs [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 39,000,000 | 39,000,000 | ||||
Deferred COVID-19 costs [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 47,800,000 | 47,800,000 | ||||
Deferred COVID-19 costs [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 13,000,000 | 13,900,000 | ||||
Deferred COVID-19 costs [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 8,400,000 | 10,400,000 | ||||
Pension & postretirement benefits expense deferral [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 32,700,000 | 30,600,000 | ||||
Pension & postretirement benefits expense deferral [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 32,700,000 | 30,600,000 | ||||
Qualified Pension Settlement Cost Deferral [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 250,900,000 | 194,700,000 | ||||
Qualified Pension Settlement Cost Deferral [Member] | Entergy Arkansas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 84,100,000 | 67,100,000 | ||||
Qualified Pension Settlement Cost Deferral [Member] | Entergy Louisiana [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 123,000,000 | 93,900,000 | ||||
Qualified Pension Settlement Cost Deferral [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 32,000,000 | 24,300,000 | ||||
Qualified Pension Settlement Cost Deferral [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 11,800,000 | 9,400,000 | ||||
Formula rate plan historical year rate adjustment [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 0 | 18,200,000 | ||||
Formula rate plan historical year rate adjustment [Member] | Entergy Mississippi [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 0 | 18,200,000 | $ 19,000,000 | |||
Advanced Metering System Surcharge [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 20,200,000 | 0 | ||||
Rate case depreciation relate back deferral [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 27,600,000 | 0 | ||||
Rate case depreciation relate back deferral [Member] | Entergy Texas [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | 27,600,000 | 0 | ||||
Gas cross-boring costs [Member] | Entergy New Orleans [Member] | ||||||
Regulatory Asset [Line Items] | ||||||
Regulatory Asset, Noncurrent | $ 10,900,000 | $ 9,900,000 |
Rate And Regulatory Matters Rat
Rate And Regulatory Matters Rate and Regulatory Matters (Details of Other Regulatory Liabilities Included in Entergy Corporation and Subsidiaries) (Details) - USD ($) $ in Thousands | 1 Months Ended | 12 Months Ended | ||||||
Jan. 01, 2018 | Dec. 31, 2017 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2017 | |
Regulatory Liability [Line Items] | ||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | ||||
Regulatory Liability, Noncurrent | $ 3,116,926 | $ 2,324,590 | ||||||
Increase (Decrease) in Regulatory Liabilities | (463,805) | 266,559 | $ (43,631) | |||||
Unrealized Gain on Nuclear Decommissioning Trust Funds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 1,826,200 | 1,237,900 | ||||||
Asset Retirement Obligation Costs [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 44,300 | 43,500 | ||||||
Vidalia Purchased Power Agreement [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 82,500 | 95,400 | ||||||
Increase (Decrease) in Regulatory Liabilities | $ 30,500 | |||||||
Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 149,500 | 101,900 | ||||||
Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 138,000 | 180,200 | ||||||
Deferred Tax Equity Partnership Earnings [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 57,900 | 43,800 | ||||||
Entergy Arkansas’s Accumulated Accelerated Grand Gulf Amortization [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 44,400 | 44,400 | ||||||
Customer sharing from resolution of the 2016-2018 IRS audit [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 98,000 | 0 | ||||||
Refund from System Energy settlement with the APSC [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 93,000 | 0 | ||||||
Securitization financing savings obligation [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 405,200 | 327,700 | ||||||
Complaints against System Energy [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 177,900 | 249,800 | ||||||
Entergy Louisiana [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | |||||||
Regulatory Liability, Noncurrent | 1,407,689 | 1,037,962 | ||||||
Increase (Decrease) in Regulatory Liabilities | (225,645) | 4,783 | 16,478 | |||||
Entergy Louisiana [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 644,000 | 438,900 | ||||||
Entergy Louisiana [Member] | Asset Retirement Obligation Costs [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 44,300 | 43,500 | ||||||
Entergy Louisiana [Member] | Vidalia Purchased Power Agreement [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 82,500 | 95,400 | ||||||
Entergy Louisiana [Member] | Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 24,100 | 44,800 | ||||||
Entergy Louisiana [Member] | Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 86,400 | 87,700 | ||||||
Entergy Louisiana [Member] | Customer sharing from resolution of the 2016-2018 IRS audit [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 38,000 | 0 | ||||||
Entergy Louisiana [Member] | Sale-leaseback and depreciation refunds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 14,100 | 0 | ||||||
Entergy Louisiana [Member] | Securitization financing savings obligation [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 405,200 | 327,700 | ||||||
Entergy Louisiana [Member] | Short-term financing interest earnings [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 36,800 | 0 | ||||||
Entergy Louisiana [Member] | Hurricane Ida insurance proceeds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 32,300 | 0 | ||||||
Entergy Arkansas [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 759,181 | 475,758 | ||||||
Increase (Decrease) in Regulatory Liabilities | (240,762) | 264,054 | (21,066) | |||||
Entergy Arkansas [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 621,600 | 428,200 | ||||||
Entergy Arkansas [Member] | Internal Restructuring Guaranteed Credits to Customers [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 6,600 | 13,200 | ||||||
Entergy Arkansas [Member] | Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 0 | 8,100 | ||||||
Entergy Arkansas [Member] | Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 10,600 | 3,900 | ||||||
Entergy Arkansas [Member] | Deferred Tax Equity Partnership Earnings [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 27,400 | 22,400 | ||||||
Entergy Arkansas [Member] | Refund from System Energy settlement with the APSC [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 93,000 | 0 | ||||||
Entergy Mississippi [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 33,696 | 79,865 | ||||||
Increase (Decrease) in Regulatory Liabilities | 59,513 | (20,165) | (21,930) | |||||
Entergy Mississippi [Member] | Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 800 | 300 | ||||||
Entergy Mississippi [Member] | Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 2,400 | 58,200 | ||||||
Entergy Mississippi [Member] | Deferred Tax Equity Partnership Earnings [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 30,500 | 21,400 | ||||||
Entergy New Orleans [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 90,434 | 20,735 | ||||||
Increase (Decrease) in Regulatory Liabilities | (66,022) | 8,639 | (4,985) | |||||
Entergy New Orleans [Member] | Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 500 | 1,200 | ||||||
Entergy New Orleans [Member] | Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 20,100 | 19,500 | ||||||
Entergy New Orleans [Member] | Customer sharing from resolution of the 2016-2018 IRS audit [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 60,000 | 0 | ||||||
Entergy New Orleans [Member] | Sale-leaseback and depreciation refunds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 9,800 | 0 | ||||||
Entergy Texas [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 43,013 | 45,247 | ||||||
Increase (Decrease) in Regulatory Liabilities | 20,122 | 30,499 | 28,747 | |||||
Entergy Texas [Member] | Other Regulatory Assets (Liabilities) [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 2,400 | 0 | ||||||
Entergy Texas [Member] | Retail Rate Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 23,800 | 10,900 | ||||||
Entergy Texas [Member] | Retail refunds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 6,200 | 25,500 | ||||||
Entergy Texas [Member] | Securitization Over-Recovery [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 300 | 8,800 | ||||||
Entergy Texas [Member] | 2022 Rate Case Settlement Relate Back [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 10,300 | 0 | ||||||
System Energy [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 782,912 | 665,024 | ||||||
Increase (Decrease) in Regulatory Liabilities | (11,009) | (21,252) | $ (40,884) | |||||
System Energy [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 560,600 | 370,800 | ||||||
System Energy [Member] | Entergy Arkansas’s Accumulated Accelerated Grand Gulf Amortization [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 44,400 | 44,400 | ||||||
System Energy [Member] | Unit Power Sales Agreement Complaint [Member] | ||||||||
Regulatory Liability [Line Items] | ||||||||
Regulatory Liability, Noncurrent | 177,900 | $ 249,800 | ||||||
Regulatory Liability, Current | $ 103,500 |
Rate And Regulatory Matters (Fu
Rate And Regulatory Matters (Fuel And Purchased Power Cost Recovery) (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | ||||
Sep. 30, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Jul. 31, 2022 | Jan. 31, 2022 | |
Deferred Fuel Cost Non Current | $ 172,201 | $ 241,085 | ||||
Asset Impairment Charges | 42,679 | (163,464) | $ 263,625 | |||
Entergy Arkansas [Member] | ||||||
Deferred Fuel Cost - Net Asset | 208,600 | |||||
Deferred Fuel Cost Non Current | 0 | 68,883 | ||||
Deferred Fuel Cost - Net Liability | (88,300) | |||||
Asset Impairment Charges | 78,434 | 0 | 0 | |||
Entergy Louisiana [Member] | ||||||
Deferred Fuel Cost - Net Asset | 192,900 | 327,300 | ||||
Deferred Fuel Cost Non Current | 168,122 | 168,122 | ||||
Entergy Mississippi [Member] | ||||||
Deferred Fuel Cost - Net Asset | 143,200 | $ 121,900 | $ 291,700 | $ 100,000 | ||
Deferred Fuel Cost - Net Liability | (130,600) | |||||
Entergy New Orleans [Member] | ||||||
Deferred Fuel Cost - Net Asset | 10,200 | 14,200 | ||||
Deferred Fuel Cost Non Current | 4,080 | 4,080 | ||||
Entergy Texas [Member] | ||||||
Deferred Fuel Cost - Net Asset | $ 139,000 | $ 258,100 | ||||
Deferred Fuel Costs [Member] | Entergy Arkansas [Member] | ||||||
Asset Impairment Charges | $ 68,900 |
Rate And Regulatory Matters R_2
Rate And Regulatory Matters Rate and Regulatory Matters (Opportunity Sales Proceeding) (Details) $ in Millions | 1 Months Ended |
Dec. 31, 2018 USD ($) | |
Entergy Arkansas [Member] | |
Payments for Legal Settlements | $ 135 |
Entergy Arkansas [Member] | Principal [Member] | |
Payments for Legal Settlements | 68 |
Entergy Arkansas [Member] | Interest Expense [Member] | |
Payments for Legal Settlements | 67 |
Entergy Louisiana [Member] | |
Proceeds from Legal Settlements | (59) |
Entergy Louisiana [Member] | Principal [Member] | |
Proceeds from Legal Settlements | (30) |
Entergy Louisiana [Member] | Interest Expense [Member] | |
Proceeds from Legal Settlements | (29) |
Entergy Mississippi [Member] | |
Proceeds from Legal Settlements | (36) |
Entergy Mississippi [Member] | Principal [Member] | |
Proceeds from Legal Settlements | (18) |
Entergy Mississippi [Member] | Interest Expense [Member] | |
Proceeds from Legal Settlements | (18) |
Entergy New Orleans [Member] | |
Proceeds from Legal Settlements | (7) |
Entergy New Orleans [Member] | Principal [Member] | |
Proceeds from Legal Settlements | (3) |
Entergy New Orleans [Member] | Interest Expense [Member] | |
Proceeds from Legal Settlements | (4) |
Entergy Texas [Member] | |
Proceeds from Legal Settlements | (33) |
Entergy Texas [Member] | Principal [Member] | |
Proceeds from Legal Settlements | (17) |
Entergy Texas [Member] | Interest Expense [Member] | |
Proceeds from Legal Settlements | $ (16) |
Income Taxes (Narrative) (Detai
Income Taxes (Narrative) (Details) - USD ($) $ in Thousands | 1 Months Ended | 3 Months Ended | 12 Months Ended | ||||||||||||
Jan. 01, 2018 | Jan. 31, 2024 | Oct. 31, 2023 | Mar. 31, 2023 | May 31, 2022 | Dec. 31, 2023 | Mar. 31, 2023 | Dec. 31, 2020 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2018 | Dec. 31, 2017 | |
Income Taxes [Line Items] | |||||||||||||||
Operating Loss Carryforwards, Valuation Allowance | $ 372,000 | $ 372,000 | $ 372,000 | ||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 1,899,000 | 1,899,000 | 3,254,000 | $ 2,256,000 | |||||||||||
Remaining Balances Of Unrecognized Tax Benefits | 541,000 | 541,000 | 3,140,000 | 3,504,000 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 39,000 | 39,000 | 50,000 | 52,000 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense | 8,000 | ||||||||||||||
Deferred Tax Assets, Valuation Allowance | 372,119 | 372,119 | 372,017 | ||||||||||||
Regulatory Liability, Noncurrent | 3,116,926 | $ 3,116,926 | 2,324,590 | ||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | |||||||||||
Regulatory Liability For Income Taxes - Current and Non Current | 1,000,000 | $ 1,000,000 | 1,300,000 | ||||||||||||
Net operating loss carryforwards | 2,857,908 | 2,857,908 | 2,065,149 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 4,612,667 | 4,612,667 | 3,643,187 | ||||||||||||
Reduction of income tax expense due reversal of UTPs | 288,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (11,000) | (4,000) | |||||||||||||
Deferred Income Tax Assets, Net | 16,367 | 16,367 | 84,100 | ||||||||||||
Deferred Income Tax Liabilities, Net | 4,245,982 | $ 4,245,982 | 4,818,837 | ||||||||||||
Reduction of income tax expense | $ 129,000 | $ 283,000 | |||||||||||||
Excise tax enacted by inflation reduction act on buyback of public company stock | 1% | ||||||||||||||
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 0 | $ 0 | 53,000 | ||||||||||||
Unrecognized Tax Benefits | 2,439,910 | $ 5,699,339 | 2,439,910 | 6,393,599 | 5,759,968 | $ 5,699,339 | |||||||||
Decrease in operating loss carryforward | 8,000,000 | 8,000,000 | |||||||||||||
Tax liability resulting from audit adjustments | 79,000 | 79,000 | |||||||||||||
Interest accrued on taxes in excess of deposits | 13,000 | 13,000 | |||||||||||||
Reversal of interest expense related to the allowance of previously unrecognized tax benefits | 24,000 | 24,000 | |||||||||||||
Increase (Reduction) in income tax resulting from Entergy Wholesale Commodities restructuring | 9,200 | ||||||||||||||
State of Louisiana Enacted Tax Legislation 2021 [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Deferred Income Tax Assets, Net | 27,000 | ||||||||||||||
Entergy Arkansas [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 57,200 | 57,200 | 377,900 | 262,100 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 7,800 | 7,800 | 4,300 | 2,700 | |||||||||||
Regulatory Liability, Noncurrent | 759,181 | 759,181 | 475,758 | ||||||||||||
Regulatory Liability For Income Taxes - Current and Non Current | 26,000 | 21,000 | 26,000 | 15,000 | $ 11,000 | $ 21,000 | |||||||||
Net operating loss carryforwards | 94,321 | 94,321 | 10,491 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 544,974 | 544,974 | $ 426,708 | ||||||||||||
Reduction to income tax expense | 9,000 | ||||||||||||||
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements | $ 2,000,000 | ||||||||||||||
State Effective Income Tax Rate, Percent | 5.30% | 5.10% | 5.90% | 6.20% | 6.50% | ||||||||||
Deferred Income Tax Liabilities, Net | 1,437,053 | $ 1,437,053 | $ 1,498,234 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 3,500 | 1,600 | $ 400 | ||||||||||||
Provision for uncertain tax position | 21,000 | ||||||||||||||
Reduction of income tax expense from the reversal of provisions for uncertain tax positions | 156,000 | ||||||||||||||
Unrecognized Tax Benefits | 69,197 | 1,364,635 | 69,197 | 1,452,819 | 1,408,494 | $ 1,364,635 | |||||||||
Decommissioning liability in COGS | 102,000 | 102,000 | |||||||||||||
Accrued increase to tax expense from the settlement of mark-to-market tax position | 40,000 | 40,000 | |||||||||||||
Decrease in operating loss carryforward | 4,000,000 | 4,000,000 | |||||||||||||
Regulatory asset for income tax associated with deficient ADIT | 35,000 | 35,000 | |||||||||||||
Reduction to income tax expense due to method of accounting | $ 1,800,000 | ||||||||||||||
Miscellaneous excess ADIT as result of 2016-2018 audit resolution | 5,000 | 5,000 | |||||||||||||
Entergy Louisiana [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 862,500 | 862,500 | 720,800 | 66,300 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 1,500 | 1,500 | 4,100 | 3,700 | |||||||||||
Regulatory Liability, Noncurrent | 1,407,689 | 1,407,689 | 1,037,962 | ||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | ||||||||||||||
Net operating loss carryforwards | 459,553 | 459,553 | 307,175 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 1,240,317 | 1,240,317 | 972,964 | ||||||||||||
Reduction to income tax expense | 42,000 | ||||||||||||||
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements | 2,000,000 | ||||||||||||||
Reduction of income tax expense due reversal of UTPs | 132,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (2,600) | ||||||||||||||
Deferred Income Tax Liabilities, Net | 2,391,442 | 2,391,442 | 2,374,878 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 400 | 300 | |||||||||||||
Reduction of income tax expense | 133,000 | 290,000 | |||||||||||||
Regulatory charge recorded as a result of reduction in income tax expense | 103,000 | 224,000 | $ 103,000 | ||||||||||||
Regulatory charge recorded as a result of reduction in income tax expense, net of tax | $ 76,000 | $ 165,000 | $ 76,000 | ||||||||||||
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 25,000 | ||||||||||||||
Unrecognized Tax Benefits | 864,043 | 640,295 | 864,043 | $ 1,350,836 | $ 604,628 | $ 640,295 | |||||||||
Decrease in operating loss carryforward | 1,000,000 | 1,000,000 | |||||||||||||
Regulatory charge to reflect credits expected to be provided to customers as a result of the resolution of the 2016-2018 IRS audit, net of tax | 28,000 | ||||||||||||||
Regulatory asset for income tax associated with deficient ADIT | 2,000 | 2,000 | |||||||||||||
Entergy Louisiana [Member] | Excess accumulated deferred income taxes as a result of the Tac Cuts and Jobs Act [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Increase (Decrease) in Regulatory Assets and Liabilities | $ 106,000 | ||||||||||||||
Entergy Louisiana [Member] | State of Louisiana Enacted Tax Legislation 2021 [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
State Effective Income Tax Rate, Percent | 7.50% | 8% | |||||||||||||
Reduction in deferred income tax expense | $ 6,000 | ||||||||||||||
Increase in state tax rate | 0.85% | ||||||||||||||
Deferred Income Tax Liabilities, Net | $ 77,000 | ||||||||||||||
Entergy Mississippi [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 1,000 | 1,000 | $ 151,200 | 51,700 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 2,100 | 2,100 | 3,100 | 2,400 | |||||||||||
Regulatory Liability, Noncurrent | 33,696 | 33,696 | 79,865 | ||||||||||||
Net operating loss carryforwards | 8,375 | 8,375 | 10,140 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 85,427 | 85,427 | 89,483 | ||||||||||||
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements | 2,000,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (1,000) | ||||||||||||||
Deferred Income Tax Liabilities, Net | 821,744 | 821,744 | 780,030 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 700 | 500 | |||||||||||||
Reduction of income tax expense from the reversal of provisions for uncertain tax positions | 1,000 | ||||||||||||||
Unrecognized Tax Benefits | 5,653 | 549,717 | 5,653 | 547,548 | 549,569 | 549,717 | |||||||||
Decrease in operating loss carryforward | 2,000,000 | 2,000,000 | |||||||||||||
Regulatory asset for income tax associated with deficient ADIT | 3,000 | 3,000 | |||||||||||||
Increase to income tax expense | (2,000) | ||||||||||||||
Entergy New Orleans [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 18,200 | 18,200 | 310,700 | 228,600 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 600 | 600 | 6,400 | 5,200 | |||||||||||
Regulatory Liability, Noncurrent | 90,434 | 90,434 | 20,735 | ||||||||||||
Net operating loss carryforwards | 26,227 | 26,227 | 12,146 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 97,833 | 97,833 | 79,887 | ||||||||||||
Reduction to income tax expense | 2,000 | ||||||||||||||
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements | 1,000,000 | ||||||||||||||
Reduction of income tax expense due reversal of UTPs | 139,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (5,800) | ||||||||||||||
Deferred Income Tax Liabilities, Net | 195,615 | 195,615 | 385,259 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 1,200 | 1,300 | |||||||||||||
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 1,000 | ||||||||||||||
Reduction of income tax expense from the reversal of provisions for uncertain tax positions | 6,000 | ||||||||||||||
Reduction of income tax expense from the reversal of a tax gain | 39,000 | ||||||||||||||
Unrecognized Tax Benefits | 19,331 | 639,546 | 19,331 | 638,726 | 639,497 | 639,546 | |||||||||
Decrease in operating loss carryforward | 1,000,000 | 1,000,000 | |||||||||||||
Regulatory charge to reflect credits expected to be provided to customers as a result of the resolution of the 2016-2018 IRS audit, net of tax | 44,000 | ||||||||||||||
Entergy New Orleans [Member] | State of Louisiana Enacted Tax Legislation 2021 [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Reduction in deferred income tax expense | 2,000 | ||||||||||||||
Deferred Income Tax Liabilities, Net | 8,000 | ||||||||||||||
Entergy Texas [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 2,900 | 2,900 | 3,300 | 2,600 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 0 | 0 | 1,100 | 1,100 | |||||||||||
Regulatory Liability, Noncurrent | 43,013 | 43,013 | 45,247 | ||||||||||||
Net operating loss carryforwards | 61 | 61 | 27,620 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 43,590 | 43,590 | 77,423 | ||||||||||||
Reduction to income tax expense | 2,000 | ||||||||||||||
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements | 2,500,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (1,100) | ||||||||||||||
Deferred Income Tax Liabilities, Net | 814,905 | 814,905 | 744,227 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 0 | 200 | |||||||||||||
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 27,000 | ||||||||||||||
Unrecognized Tax Benefits | 415,205 | 521,932 | 415,205 | 389,366 | 552,295 | 521,932 | |||||||||
System Energy [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 3,100 | 3,100 | 2,500 | 1,700 | |||||||||||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 1,900 | 1,900 | 1,900 | 12,100 | |||||||||||
Regulatory Liability, Noncurrent | 782,912 | 782,912 | 665,024 | ||||||||||||
Net operating loss carryforwards | 35,089 | 35,089 | 20,639 | ||||||||||||
Deferred Tax Assets, Net of Valuation Allowance | 317,576 | 317,576 | 294,270 | ||||||||||||
Reduction to income tax expense | 1,000 | ||||||||||||||
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (10,200) | ||||||||||||||
Deferred Income Tax Liabilities, Net | 405,744 | 405,744 | 376,070 | ||||||||||||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 0 | 200 | |||||||||||||
Unrecognized Tax Benefits | 14,301 | $ 21,652 | 14,301 | 23,702 | $ 23,356 | $ 21,652 | |||||||||
Decrease in operating loss carryforward | 40,000 | 40,000 | |||||||||||||
Subsequent Event [Member] | Entergy Arkansas [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
State Effective Income Tax Rate, Percent | 4.80% | ||||||||||||||
Customer sharing from resolution of the 2016-2018 IRS audit [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Regulatory Liability, Noncurrent | 98,000 | 98,000 | 0 | ||||||||||||
Customer sharing from resolution of the 2016-2018 IRS audit [Member] | Entergy Louisiana [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Regulatory Liability, Noncurrent | 38,000 | 38,000 | 0 | ||||||||||||
Customer sharing from resolution of the 2016-2018 IRS audit [Member] | Entergy New Orleans [Member] | |||||||||||||||
Income Taxes [Line Items] | |||||||||||||||
Regulatory Liability, Noncurrent | $ 60,000 | $ 60,000 | $ 0 |
Income Taxes (Schedule Of Incom
Income Taxes (Schedule Of Income Tax Expenses From Continuing Operations) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Current Federal Tax Expense (Benefit) | $ 60,639 | $ 32,387 | $ (5,003) |
Current State and Local Tax Expense (Benefit) | 23,014 | (3,091) | (8,995) |
Current Income Tax Expense (Benefit) | 83,653 | 29,296 | (13,998) |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | (768,941) | (67,520) | 205,891 |
Income Tax Credits and Adjustments | (5,247) | (754) | (519) |
Income Tax Expense (Benefit) | (690,535) | (38,978) | 191,374 |
Entergy Arkansas [Member] | |||
Current Federal Tax Expense (Benefit) | 33,100 | 8,015 | (20,285) |
Current State and Local Tax Expense (Benefit) | (4,201) | (1,066) | 529 |
Current Income Tax Expense (Benefit) | 28,899 | 6,949 | (19,756) |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | (126,878) | 74,802 | 96,180 |
Income Tax Credits and Adjustments | (1,231) | (855) | (1,229) |
Income Tax Expense (Benefit) | (99,210) | 80,896 | 75,195 |
Entergy Louisiana [Member] | |||
Current Federal Tax Expense (Benefit) | (142,253) | (79,079) | (24,053) |
Current State and Local Tax Expense (Benefit) | (6,397) | (1,773) | 2,459 |
Current Income Tax Expense (Benefit) | (148,650) | (80,852) | (21,594) |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | (52,451) | (77,223) | 146,786 |
Income Tax Credits and Adjustments | (4,680) | (4,778) | (4,783) |
Income Tax Expense (Benefit) | (205,781) | (162,853) | 120,409 |
Entergy Mississippi [Member] | |||
Current Federal Tax Expense (Benefit) | 20,328 | 9,242 | (5,868) |
Current State and Local Tax Expense (Benefit) | 4,142 | (6,486) | (11,506) |
Current Income Tax Expense (Benefit) | 24,470 | 2,756 | (17,374) |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | 30,690 | 48,443 | 60,861 |
Income Tax Credits and Adjustments | (796) | 3,665 | 1,836 |
Income Tax Expense (Benefit) | 54,364 | 54,864 | 45,323 |
Entergy New Orleans [Member] | |||
Current Federal Tax Expense (Benefit) | (99,343) | 1,074 | (6,724) |
Current State and Local Tax Expense (Benefit) | (5,854) | 6,221 | (413) |
Current Income Tax Expense (Benefit) | (105,197) | 7,295 | (7,137) |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | (84,744) | 16,814 | 12,870 |
Income Tax Credits and Adjustments | (32) | 168 | 203 |
Income Tax Expense (Benefit) | (189,973) | 24,277 | 5,936 |
Entergy Texas [Member] | |||
Current Federal Tax Expense (Benefit) | 2,851 | 37,471 | (189) |
Current State and Local Tax Expense (Benefit) | 3,719 | 2,260 | 1,261 |
Current Income Tax Expense (Benefit) | 6,570 | 39,731 | 1,072 |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | 57,066 | 11,520 | 25,087 |
Income Tax Credits and Adjustments | (764) | (630) | (633) |
Income Tax Expense (Benefit) | 62,872 | 50,621 | 25,526 |
System Energy [Member] | |||
Current Federal Tax Expense (Benefit) | 337 | (11,720) | 29,416 |
Current State and Local Tax Expense (Benefit) | (1,570) | 581 | (10,258) |
Current Income Tax Expense (Benefit) | (1,233) | (11,139) | 19,158 |
Deferred Income Tax Expense Benefit And Non current Income Tax Expense Benefit | 31,005 | (83,369) | (25,229) |
Income Tax Credits and Adjustments | (2,260) | (1,680) | (4,094) |
Income Tax Expense (Benefit) | $ 32,032 | $ (92,828) | $ (1,977) |
Income Taxes (Schedule Of Statu
Income Taxes (Schedule Of Statutory Income Tax Rate To Income Before Taxes) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||||||
Jan. 01, 2018 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2017 | |
Net Income (Loss) | $ 2,356,536 | $ 1,103,166 | $ 1,118,492 | ||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 5,774 | (6,028) | 227 | ||||
Consolidated net income | 2,362,310 | 1,097,138 | 1,118,719 | ||||
Income Tax Expense (Benefit) | (690,535) | (38,978) | 191,374 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | $ 1,671,775 | 1,058,160 | 1,310,093 | ||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | |||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | $ 351,073 | 222,214 | 275,120 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 70,144 | 61,368 | 79,273 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (27,901) | (32,143) | (57,556) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (20,172) | (14,156) | (14,799) | ||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 7,978 | 7,740 | 7,695 | ||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | (1,374) | 1,011 | (5,585) | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 842,769 | 0 | 0 | ||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 9,102 | (34,899) | (66,478) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | 0 | 0 | 27,108 | ||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 18,884 | 34,423 | 16,533 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | (8,697) | (2,754) | (2,600) | ||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 3,836 | $ 3,656 | $ 2,269 | ||||
Effective Income Tax Rate Reconciliation, Percent | (41.30%) | (3.70%) | 14.60% | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | $ 129,034 | $ 282,620 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | 105,649 | 0 | 0 | ||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | (12,662) | 0 | ||||
Entergy Arkansas [Member] | |||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (5,231) | (4,358) | (18,092) | ||||
Consolidated net income | 396,850 | 292,887 | 298,484 | ||||
Income Tax Expense (Benefit) | (99,210) | 80,896 | 75,195 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 297,640 | 373,783 | 373,679 | ||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 297,640 | 373,783 | 373,679 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 62,504 | 78,494 | 78,473 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 13,291 | 17,981 | 19,633 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (8,812) | (12,466) | (16,078) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (4,093) | (3,437) | (3,207) | ||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 1,201 | 1,201 | 1,201 | ||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | 1,105 | 106 | (814) | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | (159,588) | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | (6,095) | 0 | (5,845) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | 398 | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 2,600 | 1,600 | 353 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | (1,258) | 2,766 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 1,079 | $ 1,077 | $ 717 | ||||
Effective Income Tax Rate Reconciliation, Percent | (33.30%) | 21.60% | 20.10% | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ 0 | $ 0 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | 0 | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | ||||||
Entergy Louisiana [Member] | |||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,988 | 1,366 | 0 | ||||
Consolidated net income | 1,273,370 | 855,870 | 653,984 | ||||
Income Tax Expense (Benefit) | (205,781) | (162,853) | 120,409 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 1,067,589 | 693,017 | 774,393 | ||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | ||||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 1,067,589 | 693,017 | 774,393 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 224,194 | 145,534 | 162,623 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 51,899 | 44,244 | 41,030 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (5,535) | (6,347) | (14,123) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (6,754) | (5,513) | (6,016) | ||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 4,625 | 4,720 | 4,729 | ||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | 126 | 3,467 | (2,655) | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 179,111 | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 14,032 | (13,164) | (24,323) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | (6,126) | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | (400) | 400 | 300 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 1,601 | $ 1,590 | $ 1,229 | ||||
Effective Income Tax Rate Reconciliation, Percent | (19.30%) | (23.50%) | 15.50% | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ (62,116) | $ (38,735) | $ (26,801) | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | (133,443) | (289,609) | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | (105,649) | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | ||||||
Entergy Mississippi [Member] | |||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (10,302) | (21,355) | 0 | ||||
Consolidated net income | 181,969 | 176,267 | 166,834 | ||||
Income Tax Expense (Benefit) | 54,364 | 54,864 | 45,323 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 236,333 | 231,131 | 212,157 | ||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 236,333 | 231,131 | 212,157 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 49,630 | 48,538 | 44,553 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 11,133 | 9,659 | 9,305 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (5,290) | (7,726) | (8,133) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (1,796) | (1,286) | (1,701) | ||||
Effective Income Tax Rate Reconciliation, Tax Charge, Amount | (64) | ||||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 223 | 223 | |||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | 3,534 | 4,837 | 124 | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 3,291 | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 0 | 0 | 0 | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | 395 | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 300 | 700 | 465 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 367 | $ 365 | $ 251 | ||||
Effective Income Tax Rate Reconciliation, Percent | 23% | 23.70% | 21.40% | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ 0 | $ 0 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | 0 | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | ||||||
Entergy New Orleans [Member] | |||||||
Consolidated net income | 228,938 | 64,101 | 31,798 | ||||
Income Tax Expense (Benefit) | (189,973) | 24,277 | 5,936 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 38,965 | 88,378 | 37,734 | ||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 38,965 | 88,378 | 37,734 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 8,183 | 18,559 | 7,924 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 1,907 | 6,733 | 2,579 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (1,353) | (1,908) | (4,332) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (309) | (174) | (498) | ||||
Effective Income Tax Rate Reconciliation, Tax Charge, Amount | (175) | ||||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 25 | 56 | |||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | (1,913) | 230 | 1,559 | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 198,424 | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 1,147 | (752) | (1,028) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | (1,569) | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 600 | 1,200 | 1,200 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 214 | $ 214 | $ 157 | ||||
Effective Income Tax Rate Reconciliation, Percent | (487.50%) | 27.50% | 15.70% | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ 0 | $ 0 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | 0 | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | ||||||
Entergy Texas [Member] | |||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,072 | 2,072 | 1,909 | ||||
Consolidated net income | 291,273 | 303,327 | 228,824 | ||||
Income Tax Expense (Benefit) | 62,872 | 50,621 | 25,526 | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 354,145 | 353,948 | 254,350 | ||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 354,145 | 353,948 | 254,350 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 74,370 | 74,329 | 53,413 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 2,574 | 2,175 | 1,553 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (6,394) | (3,010) | (2,115) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (5,920) | (2,841) | (2,077) | ||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 748 | 614 | 617 | ||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | 1,493 | 765 | (475) | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 3,112 | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 17 | (20,983) | (21,929) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | 216 | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 211 | 420 | (2,716) | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 381 | $ 380 | $ 273 | ||||
Effective Income Tax Rate Reconciliation, Percent | 17.80% | 14.30% | 10% | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ 0 | $ 0 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | 0 | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | 0 | ||||||
System Energy [Member] | |||||||
Consolidated net income | 108,772 | (276,593) | 106,814 | ||||
Income Tax Expense (Benefit) | 32,032 | (92,828) | (1,977) | ||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 140,804 | (369,421) | 104,837 | ||||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 140,804 | (369,421) | 104,837 | ||||
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | 29,569 | (77,578) | 22,016 | ||||
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount | 5,798 | (16,727) | 5,385 | ||||
Effective Income Tax Rate Reconciliation, Regulatory Differences Utility Plant Items | (517) | (686) | (12,776) | ||||
Effective Income Tax Rate Reconciliation, Equity Component Of Allowance For Funds Used During Construction | (1,301) | (905) | (1,300) | ||||
Effective Income Tax Rate Reconciliation, Tax Credit, Amount | 1,155 | 1,155 | 1,155 | ||||
Effective Income Tax Rate Reconciliation, Flow Through Permanent Differences | (191) | (641) | (1,235) | ||||
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | 1,575 | ||||||
Effective Income Tax Rate Reconciliation, Amortization of Excess ADIT | 0 | 0 | (13,354) | ||||
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount | 115 | ||||||
Effective Income Tax Rate Reconciliation, Provision For Uncertain Tax Positions | 1,200 | (8,000) | 200 | ||||
Effective Income Tax Rate Reconciliation, Valuation allowance | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount | $ 204 | $ 202 | $ 127 | ||||
Effective Income Tax Rate Reconciliation, Percent | 22.70% | 25.10% | (1.90%) | ||||
Effective Income Tax Rate Reconciliation, Non-taxable dividend income | $ 0 | $ 0 | $ 0 | ||||
Effective Income Tax Rate Reconciliation, Entergy Louisiana securitization | 0 | 0 | |||||
Effective Income Tax Rate Reconciliation, Reversal of Regulatory Liability for Excess ADIT | $ 0 | ||||||
Effective Income Tax Rate Reconciliation, System Energy Sale-Leaseback Order | $ 12,662 |
Income Taxes (Significant Compo
Income Taxes (Significant Components Of Accumulated Deferred Income Taxes And Taxes Accrued) (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Deferred Tax Liabilities, Property, Plant and Equipment | $ (6,192,156) | $ (5,270,010) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (989,405) | (937,554) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | (467,267) | (318,570) |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (363,829) | (336,496) |
Deferred Tax Liabilities, Combined Unitary State Taxes | (8,783) | (10,335) |
Deferred Tax Liability, Deferred Fuel | (69,436) | (181,222) |
Deferred Tax Liabilities, Other | (251,107) | (333,421) |
Deferred Tax Liabilities, Net | (8,420,069) | (7,426,814) |
Regulatory liabilities | 1,247,530 | 1,108,075 |
Pension and other post-employment benefits | 116,222 | 141,399 |
Compensation | 81,226 | 76,317 |
Accumulated deferred investment tax credit | 55,928 | 57,501 |
Provision for allowances and contingencies | 149,479 | 97,545 |
Net operating loss carryforwards | 2,857,908 | 2,065,149 |
Capital losses and miscellaneous tax credits | 107,009 | 28,876 |
Valuation allowance | (372,119) | (372,017) |
Other | (220,055) | (245,236) |
Deferred Tax Assets, Net of Valuation Allowance | 4,612,667 | 3,643,187 |
Non-current accrued taxes (including unrecognized tax benefits) | (422,213) | (951,110) |
Deferred Tax Liabilities, Deferred Expense | (75,612) | (3,993) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 2,474 | 35,213 |
Deferred tax asset Nuclear Decommissioning Liabilities | 147,011 | 173,201 |
Accumulated deferred income taxes and taxes accrued | (4,229,615) | (4,734,737) |
Deferred Tax Asset, Unbilled Revenue | (2,418) | (21,905) |
Entergy Arkansas [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (1,421,272) | (1,181,456) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (241,427) | (244,624) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | (154,106) | (107,858) |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (96,853) | (93,139) |
Deferred Tax Liabilities, Deferred Fuel | 0 | (35,205) |
Deferred Tax Liabilities, Other | (21,187) | (76,813) |
Deferred Tax Liabilities, Net | (1,918,852) | (1,747,391) |
Regulatory liabilities | 296,278 | 236,318 |
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions | (28,868) | (28,463) |
Compensation | 4,054 | 3,361 |
Accumulated deferred investment tax credit | 6,761 | 7,171 |
Provision for allowances and contingencies | 23,956 | 26,432 |
Net operating loss carryforwards | 94,321 | 10,491 |
Other | (17,072) | (24,969) |
Deferred Tax Assets, Net of Valuation Allowance | 544,974 | 426,708 |
Non-current accrued taxes (including unrecognized tax benefits) | (63,175) | (177,551) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 0 | 0 |
Deferred Tax Liabilities, Power Purchase Agreements | (15,993) | 8,296 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 7,137 | 719 |
Deferred tax asset Nuclear Decommissioning Liabilities | 118,301 | 139,499 |
Accumulated deferred income taxes and taxes accrued | (1,437,053) | (1,498,234) |
Deferred Tax Asset, Unbilled Revenue | (5,962) | (6,211) |
Entergy Louisiana [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (2,639,079) | (2,513,138) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (500,395) | (457,102) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | (173,402) | (118,172) |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (82,305) | (82,891) |
Deferred Tax Liabilities, Deferred Fuel | (17,065) | (49,792) |
Deferred Tax Liabilities, Other | (126,952) | (126,350) |
Deferred Tax Liabilities, Net | (3,651,490) | (3,389,963) |
Regulatory liabilities | 575,459 | 508,594 |
Pension and other post-employment benefits | 46,837 | 52,414 |
Compensation | 6,078 | 5,207 |
Accumulated deferred investment tax credit | 27,902 | 29,271 |
Provision for allowances and contingencies | 70,297 | 15,741 |
Net operating loss carryforwards | 459,553 | 307,175 |
Other | (52,438) | (41,310) |
Deferred Tax Assets, Net of Valuation Allowance | 1,240,317 | 972,964 |
Non-current accrued taxes (including unrecognized tax benefits) | (19,731) | (42,121) |
Deferred Tax Liabilities, Deferred Expense | (20,375) | (2,405) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 0 | 31,337 |
Deferred Tax Liabilities, Power Purchase Agreements | 112,292 | 11,181 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 13,073 | 2,774 |
Deferred tax asset Nuclear Decommissioning Liabilities | 9,055 | 12,883 |
Accumulated deferred income taxes and taxes accrued | (2,391,442) | (2,374,878) |
Entergy Mississippi [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (810,120) | (691,675) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (41,519) | (44,358) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | 0 | 0 |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (24,342) | (22,256) |
Deferred Tax Liabilities, Deferred Fuel | (21,137) | (37,333) |
Deferred Tax Liabilities, Other | (6,844) | (26,752) |
Deferred Tax Liabilities, Net | (902,822) | (822,374) |
Regulatory liabilities | 54,586 | 54,454 |
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions | (10,064) | (9,196) |
Compensation | 3,649 | 2,316 |
Accumulated deferred investment tax credit | 3,446 | 3,641 |
Provision for allowances and contingencies | 10,072 | 10,300 |
Net operating loss carryforwards | 8,375 | 10,140 |
Other | (1,556) | (6,849) |
Deferred Tax Assets, Net of Valuation Allowance | 85,427 | 89,483 |
Non-current accrued taxes (including unrecognized tax benefits) | (4,349) | (47,139) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 0 | 0 |
Deferred Tax Liabilities, Power Purchase Agreements | (1,140) | 0 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 7,613 | 5,152 |
Deferred tax asset Nuclear Decommissioning Liabilities | 0 | 1 |
Accumulated deferred income taxes and taxes accrued | (821,744) | (780,030) |
Deferred Tax Asset, Unbilled Revenue | (6,194) | (5,826) |
Entergy New Orleans [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (272,187) | (115,841) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (23,618) | (24,738) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | 0 | 0 |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (9,216) | (9,604) |
Deferred Tax Liabilities, Deferred Fuel | (1,563) | (2,560) |
Deferred Tax Liabilities, Other | (4,270) | (21,977) |
Deferred Tax Liabilities, Net | (323,370) | (184,092) |
Regulatory liabilities | 42,921 | 27,438 |
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions | (19,354) | (18,114) |
Compensation | 1,268 | 1,107 |
Accumulated deferred investment tax credit | 4,431 | 4,438 |
Provision for allowances and contingencies | 25,846 | 26,671 |
Net operating loss carryforwards | 26,227 | 12,146 |
Other | (235) | (11,105) |
Deferred Tax Assets, Net of Valuation Allowance | 97,833 | 79,887 |
Non-current accrued taxes (including unrecognized tax benefits) | (29,922) | (281,054) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 0 | 0 |
Deferred Tax Liabilities, Power Purchase Agreements | 12,516 | 9,372 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 15,684 | 11,006 |
Deferred tax asset Nuclear Decommissioning Liabilities | 0 | 0 |
Accumulated deferred income taxes and taxes accrued | (195,615) | (385,259) |
Deferred Tax Asset, Unbilled Revenue | (1,045) | (4,090) |
Entergy Texas [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (671,072) | (614,134) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (104,562) | (95,717) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | 0 | 0 |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (17,522) | (18,111) |
Deferred Tax Liabilities, Deferred Fuel | (29,194) | (54,204) |
Deferred Tax Liabilities, Other | (3,301) | (4,126) |
Deferred Tax Liabilities, Net | (831,589) | (812,182) |
Regulatory liabilities | 41,137 | 47,248 |
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions | (21,977) | (20,867) |
Compensation | 2,181 | 1,712 |
Accumulated deferred investment tax credit | 1,672 | 1,829 |
Provision for allowances and contingencies | 8,659 | 7,755 |
Net operating loss carryforwards | 61 | 27,620 |
Other | (1,740) | (729) |
Deferred Tax Assets, Net of Valuation Allowance | 43,590 | 77,423 |
Non-current accrued taxes (including unrecognized tax benefits) | (26,906) | (9,468) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 1,387 | 3,876 |
Deferred Tax Liabilities, Power Purchase Agreements | 4,551 | 22,014 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 1,655 | 3,728 |
Deferred tax asset Nuclear Decommissioning Liabilities | 97 | 97 |
Accumulated deferred income taxes and taxes accrued | (814,905) | (744,227) |
Deferred Tax Asset, Unbilled Revenue | (8,365) | (7,572) |
System Energy [Member] | ||
Deferred Tax Liabilities, Property, Plant and Equipment | (450,559) | (448,010) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (76,522) | (68,742) |
Deferred Tax Liabilities Nuclear Decommissioning Trusts | (139,858) | (92,527) |
Deferred Tax Liability, Tax Deferred Expense, Compensation and Benefits, Pensions | (18,895) | (17,889) |
Deferred Tax Liabilities, Deferred Fuel | (37) | (128) |
Deferred Tax Liabilities, Other | (9,051) | (14,364) |
Deferred Tax Liabilities, Net | (694,922) | (641,660) |
Regulatory liabilities | 240,310 | 237,452 |
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions | (2,641) | (2,481) |
Compensation | 406 | 308 |
Accumulated deferred investment tax credit | 11,717 | 11,151 |
Provision for allowances and contingencies | 225 | 0 |
Net operating loss carryforwards | 35,089 | 20,639 |
Other | 0 | 0 |
Deferred Tax Assets, Net of Valuation Allowance | 317,576 | 294,270 |
Non-current accrued taxes (including unrecognized tax benefits) | (28,398) | (28,680) |
Deferred Tax Liabilities, Accumulated Storm Damage Provision | 0 | 0 |
Deferred Tax Liabilities, Power Purchase Agreements | 0 | 0 |
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits | 13,211 | 8,261 |
Deferred tax asset Nuclear Decommissioning Liabilities | 19,259 | 18,940 |
Accumulated deferred income taxes and taxes accrued | (405,744) | (376,070) |
Deferred Tax Asset, Unbilled Revenue | $ 0 | $ 0 |
Income Taxes (Schedule Of Estim
Income Taxes (Schedule Of Estimated Tax Attributes Carryovers And Their Expiration Dates) (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Operating Loss Carryforwards [Line Items] | ||
Deferred Tax Assets, Capital Loss Carryforwards | $ 107,009 | $ 28,876 |
Internal Revenue Service (IRS) [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 4,200,000 | |
Operating Loss Carryforwards | 13,800,000 | |
Internal Revenue Service (IRS) [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 0 | |
Operating Loss Carryforwards | 500,000 | |
Tax Credit Carryforward, Amount | 10,000 | |
Internal Revenue Service (IRS) [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 800,000 | |
Operating Loss Carryforwards | 2,800,000 | |
Tax Credit Carryforward, Amount | 16,900 | |
Internal Revenue Service (IRS) [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 0 | |
Operating Loss Carryforwards | 10,800 | |
Tax Credit Carryforward, Amount | 3,900 | |
Internal Revenue Service (IRS) [Member] | Entergy New Orleans [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 100,000 | |
Operating Loss Carryforwards | $ 17,700 | |
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2037 | |
Tax Credit Carryforward, Amount | $ 16,100 | |
Internal Revenue Service (IRS) [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 0 | |
Operating Loss Carryforwards | 1,800,000 | |
Tax Credit Carryforward, Amount | 800 | |
Internal Revenue Service (IRS) [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Pre January 1, 2018 | 0 | |
Operating Loss Carryforwards | 100,000 | |
Tax Credit Carryforward, Amount | 4,800 | |
State and Local Jurisdiction [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 3,900,000 | |
Operating Loss Carryforwards, No Expiration | 11,100,000 | |
Deferred Tax Assets, Charitable Contribution Carryforwards | 523,600 | |
State and Local Jurisdiction [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 400,000 | |
Tax Credit Carryforward, Amount | 0 | |
State and Local Jurisdiction [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 5,700,000 | |
Tax Credit Carryforward, Amount | 0 | |
State and Local Jurisdiction [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 100,000 | |
Tax Credit Carryforward, Amount | 8,000 | |
State and Local Jurisdiction [Member] | Entergy New Orleans [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 200,000 | |
Tax Credit Carryforward, Amount | 0 | |
State and Local Jurisdiction [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | $ 1,000 | |
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2028 | |
Tax Credit Carryforward, Amount | $ 1,600 | |
State and Local Jurisdiction [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards | 200,000 | |
Tax Credit Carryforward, Amount | 19,000 | |
Other Federal And State [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Amount | $ 124,900 | |
Minimum [Member] | Internal Revenue Service (IRS) [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2028 | |
Minimum [Member] | Internal Revenue Service (IRS) [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2035 | |
Minimum [Member] | State and Local Jurisdiction [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2028 | |
Minimum [Member] | State and Local Jurisdiction [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2028 | |
Minimum [Member] | State and Local Jurisdiction [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2040 | |
Tax Credit Carryforward, Expiration Date | Dec. 31, 2024 | |
Minimum [Member] | State and Local Jurisdiction [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2027 | |
Minimum [Member] | State and Local Jurisdiction [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2024 | |
Minimum [Member] | Other Federal And State [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2024 | |
Minimum [Member] | Other Federal And State [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2038 | |
Minimum [Member] | Other Federal And State [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2035 | |
Minimum [Member] | Other Federal And State [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2038 | |
Minimum [Member] | Other Federal And State [Member] | Entergy New Orleans [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2037 | |
Minimum [Member] | Other Federal And State [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2039 | |
Minimum [Member] | Other Federal And State [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2029 | |
Minimum [Member] | Other Federal [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2024 | |
Maximum [Member] | Internal Revenue Service (IRS) [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2037 | |
Maximum [Member] | Internal Revenue Service (IRS) [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2037 | |
Maximum [Member] | State and Local Jurisdiction [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2042 | |
Maximum [Member] | State and Local Jurisdiction [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2032 | |
Maximum [Member] | State and Local Jurisdiction [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Operating Loss Carryforwards, Expiration Date | Dec. 31, 2042 | |
Tax Credit Carryforward, Expiration Date | Dec. 31, 2026 | |
Maximum [Member] | State and Local Jurisdiction [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2033 | |
Maximum [Member] | State and Local Jurisdiction [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2027 | |
Maximum [Member] | Other Federal And State [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | Entergy Arkansas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | Entergy Louisiana [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | Entergy Mississippi [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | Entergy New Orleans [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | Entergy Texas [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal And State [Member] | System Energy [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2043 | |
Maximum [Member] | Other Federal [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Tax Credit Carryforward, Expiration Date | Dec. 31, 2037 |
Income Taxes (Schedule Of Unrec
Income Taxes (Schedule Of Unrecognized Tax Benefits) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Unrecognized Tax Benefits, Beginning Balance | $ 6,393,599 | $ 5,759,968 | $ 5,699,339 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 332,884 | 792,134 | 101,623 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 194,894 | 37,259 | 33,419 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (1,300,381) | (195,762) | (74,413) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (3,181,086) | 0 | 0 |
Unrecognized Tax Benefits, Ending Balance | 2,439,910 | 6,393,599 | 5,759,968 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 279,426 | 745,387 | 712,169 |
Remaining Balances Of Unrecognized Tax Benefits | 541,000 | 3,140,000 | 3,504,000 |
Net operating loss carryforwards | 2,857,908 | 2,065,149 | |
Cash Paid To Taxing Authorities | 0 | 82,000 | 60,000 |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (2,160,484) | (5,566,212) | (4,987,799) |
Entergy Arkansas [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 1,452,819 | 1,408,494 | 1,364,635 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 2,249 | 40,502 | 30,419 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 6,233 | 15,013 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (148,558) | (2,410) | (1,573) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (1,237,313) | ||
Unrecognized Tax Benefits, Ending Balance | 69,197 | 1,452,819 | 1,408,494 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 34,514 | 175,405 | 415,851 |
Net operating loss carryforwards | 94,321 | 10,491 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (34,683) | (1,277,414) | (992,643) |
Entergy Louisiana [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 1,350,836 | 604,628 | 640,295 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 332,320 | 750,320 | 13,437 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 10,262 | 9,304 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (458,072) | (14,374) | (58,408) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (361,041) | ||
Unrecognized Tax Benefits, Ending Balance | 864,043 | 1,350,836 | 604,628 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 128,431 | 21,920 | 0 |
Net operating loss carryforwards | 459,553 | 307,175 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (735,612) | (1,328,916) | (604,628) |
Entergy Mississippi [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 547,548 | 549,569 | 549,717 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 209 | 185 | 684 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 1,122 | 1,504 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (16,853) | (3,328) | (2,336) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (525,251) | ||
Unrecognized Tax Benefits, Ending Balance | 5,653 | 547,548 | 549,569 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 1,875 | 42,608 | 160,841 |
Net operating loss carryforwards | 8,375 | 10,140 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (3,778) | (504,940) | (388,728) |
Entergy New Orleans [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 638,726 | 639,497 | 639,546 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 78 | 72 | 1,050 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 393 | 6 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (191,336) | (1,236) | (1,105) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (428,137) | ||
Unrecognized Tax Benefits, Ending Balance | 19,331 | 638,726 | 639,497 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 7,610 | 182,798 | 154,598 |
Net operating loss carryforwards | 26,227 | 12,146 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (11,721) | (455,928) | (484,899) |
Entergy Texas [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 389,366 | 552,295 | 521,932 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 196 | 173 | 32,616 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 94,793 | 801 | 2,315 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (67,156) | (163,903) | (4,568) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (1,994) | ||
Unrecognized Tax Benefits, Ending Balance | 415,205 | 389,366 | 552,295 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 33,644 | 12,312 | 11,601 |
Net operating loss carryforwards | 61 | 27,620 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | (381,561) | (377,054) | (540,694) |
System Energy [Member] | |||
Unrecognized Tax Benefits, Beginning Balance | 23,702 | 23,356 | 21,652 |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 752 | 690 | 1,753 |
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 761 | 1,897 |
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions | (9,532) | (1,105) | (1,946) |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | (621) | ||
Unrecognized Tax Benefits, Ending Balance | 14,301 | 23,702 | 23,356 |
Unrecognized Tax Benefits Net Of Unused Tax Attributes And Payments | 0 | 0 | 14,780 |
Net operating loss carryforwards | 35,089 | 20,639 | |
Offset to gross unrecognized tax benefits, credit and loss carryforward | $ (14,301) | $ (23,702) | $ (8,576) |
Income Taxes (Summary Of Unreco
Income Taxes (Summary Of Unrecognized Benefits That Would Affect Effective Income Tax Rate) (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 |
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | $ 1,899 | $ 3,254 | $ 2,256 |
Entergy Arkansas [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 57.2 | 377.9 | 262.1 |
Entergy Louisiana [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 862.5 | 720.8 | 66.3 |
Entergy Mississippi [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 1 | 151.2 | 51.7 |
Entergy New Orleans [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 18.2 | 310.7 | 228.6 |
Entergy Texas [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 2.9 | 3.3 | 2.6 |
System Energy [Member] | |||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | $ 3.1 | $ 2.5 | $ 1.7 |
Income Taxes (Summary Of Accrue
Income Taxes (Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 |
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | $ 39 | $ 50 | $ 52 |
Entergy Arkansas [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 7.8 | 4.3 | 2.7 |
Entergy Louisiana [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 1.5 | 4.1 | 3.7 |
Entergy Mississippi [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 2.1 | 3.1 | 2.4 |
Entergy New Orleans [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 0.6 | 6.4 | 5.2 |
Entergy Texas [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 0 | 1.1 | 1.1 |
System Energy [Member] | |||
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | $ 1.9 | $ 1.9 | $ 12.1 |
Income Taxes Income Taxes (Summ
Income Taxes Income Taxes (Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | $ (11) | $ (4) | |
Entergy Arkansas [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 3.5 | $ 1.6 | 0.4 |
Entergy Louisiana [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 0.4 | 0.3 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (2.6) | ||
Entergy Mississippi [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 0.7 | 0.5 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (1) | ||
Entergy New Orleans [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 1.2 | 1.3 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (5.8) | ||
Entergy Texas [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | 0 | 0.2 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | (1.1) | ||
System Energy [Member] | |||
Unrecognized Tax Benefits, Interest on Income Taxes Expense | $ 0 | $ 0.2 | |
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense | $ (10.2) |
Income Taxes Income Taxes (Tax
Income Taxes Income Taxes (Tax Cuts and Jobs Act) (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Reduction to Regulatory Liability due to return of unprotected excess ADIT | $ 0 | $ 53,000 |
Entergy Arkansas [Member] | ||
Net Regulatory Liabilities for Income Taxes | 392 | 435 |
Entergy Louisiana [Member] | ||
Net Regulatory Liabilities for Income Taxes | 194 | 338 |
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 25,000 | |
Entergy Mississippi [Member] | ||
Net Regulatory Liabilities for Income Taxes | 189 | 202 |
Entergy New Orleans [Member] | ||
Net Regulatory Liabilities for Income Taxes | 36 | 40 |
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 1,000 | |
Entergy Texas [Member] | ||
Net Regulatory Liabilities for Income Taxes | 115 | 133 |
Reduction to Regulatory Liability due to return of unprotected excess ADIT | 27,000 | |
System Energy [Member] | ||
Net Regulatory Liabilities for Income Taxes | $ 107 | $ 111 |
Revolving Credit Facilities, _3
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Narrative) (Details) | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Commercial Paper Program [Member] | |
Commercial Paper program limit | $ 2,000,000,000 |
Commercial Paper | $ 1,138,100,000 |
Debt, Weighted Average Interest Rate | 5.44% |
Entergy Louisiana Waterford VIE [Member] | |
Line of credit facility commitment fee as a percentage of undrawn commitment amount | 0.10% |
Entergy Louisiana River Bend VIE [Member] | |
Line of credit facility commitment fee as a percentage of undrawn commitment amount | 0.10% |
System Energy VIE [Member] | |
Line of credit facility commitment fee as a percentage of undrawn commitment amount | 0.10% |
Entergy Arkansas VIE [Member] | |
Line of credit facility commitment fee as a percentage of undrawn commitment amount | 0.10% |
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member] | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 30,000,000 |
Line of Credit Facility, Maximum Borrowing Capacity | 150,000,000 |
Long-Term Line of Credit | 0 |
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member] | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 5,000,000 |
Line of Credit Facility, Maximum Borrowing Capacity | 150,000,000 |
Long-Term Line of Credit | 0 |
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Mississippi [Member] | |
Line of Credit Facility, Maximum Borrowing Capacity | 150,000,000 |
Long-Term Line of Credit | 0 |
Credit Facility Of Three Hundred and Fifty Million [Member] | Entergy Louisiana [Member] | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 15,000,000 |
Line of Credit Facility, Maximum Borrowing Capacity | 350,000,000 |
Long-Term Line of Credit | 0 |
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member] | |
Line of Credit Facility, Maximum Borrowing Capacity | 25,000,000 |
Long-Term Line of Credit | 0 |
Credit Facility Of Twenty Five Million [Member] | Entergy New Orleans [Member] | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 10,000,000 |
Line of Credit Facility, Maximum Borrowing Capacity | 25,000,000 |
Long-Term Line of Credit | $ 0 |
Credit Facility of Three Point Five Billion [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.225% |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 20,000,000 |
Line of Credit Facility, Maximum Borrowing Capacity | 3,500,000,000 |
Long-Term Line of Credit | $ 0 |
Credit Facility of Three Point Five Billion [Member] | Credit Facility [Member] | |
Debt, Weighted Average Interest Rate | 6.52% |
Credit Facility of One Hundred and Thirty Nine Million [Member] | Entergy Nuclear Vermont Yankee [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.20% |
Line of Credit Facility, Maximum Borrowing Capacity | $ 139,000,000 |
Debt, Weighted Average Interest Rate | 6.61% |
Long-Term Line of Credit | $ 139,000,000 |
Credit Facility of Eighty Million [Member] | Entergy Louisiana [Member] | |
Letters of credit posted to cover financial transmission right exposure | 500,000 |
Credit Facility of Eighty Million [Member] | Entergy Texas [Member] | |
Letters of credit posted to cover financial transmission right exposure | 100,000 |
Credit Facility of Eighty Million [Member] | Entergy Arkansas [Member] | |
Letters of credit posted to cover financial transmission right exposure | 1,200,000 |
Credit Facility of Eighty Million [Member] | Entergy Arkansas VIE [Member] | |
Long-Term Line of Credit | $ 70,200,000 |
Minimum [Member] | Entergy Louisiana [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Minimum [Member] | Entergy Texas [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Minimum [Member] | Entergy Arkansas [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Minimum [Member] | Entergy Mississippi [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Minimum [Member] | Entergy New Orleans [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Maximum [Member] | Entergy Louisiana [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Consolidated debt ratio of lessees total capitalization | 70% |
Maximum [Member] | Entergy Texas [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Maximum [Member] | System Energy [Member] | |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Consolidated debt ratio of lessees total capitalization | 70% |
Maximum [Member] | Entergy Arkansas [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Consolidated debt ratio of lessees total capitalization | 70% |
Maximum [Member] | Entergy Mississippi [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Maximum [Member] | Entergy New Orleans [Member] | |
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Public Utilities, Approved Debt Capital Structure, Percentage | 65% |
Maximum [Member] | Credit Facility of Three Point Five Billion [Member] | |
Consolidated debt ratio | 65% |
Revolving Credit Facilities, _4
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) - Credit Facility of Three Point Five Billion [Member] $ in Thousands | Dec. 31, 2023 USD ($) |
Line of Credit Facility, Maximum Borrowing Capacity | $ 3,500,000 |
Long-Term Line of Credit | 0 |
Letters of Credit Outstanding, Amount | 3,000 |
Line of Credit Facility, Remaining Borrowing Capacity | 3,497,000 |
Letters of Credit Outstanding, Amount | 3,000 |
Line of Credit Facility, Remaining Borrowing Capacity | $ 3,497,000 |
Revolving Credit Facilities, _5
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Credit Facilities) (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member] | |
Line of Credit Facility, Expiration Date | Apr. 30, 2024 |
Line of Credit Facility, Maximum Borrowing Capacity | $ 25 |
Line of Credit Facility, Interest Rate During Period | 7.29% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | $ 0 |
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2028 |
Line of Credit Facility, Maximum Borrowing Capacity | $ 150 |
Line of Credit Facility, Interest Rate During Period | 6.58% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | 0 |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 5 |
Entergy Louisiana [Member] | Credit Facility Of Three Hundred and Fifty Million [Member] | |
Line of Credit Facility, Maximum Borrowing Capacity | $ 350 |
Line of Credit Facility, Interest Rate During Period | 6.71% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | 0 |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 15 |
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2028 |
Entergy Mississippi [Member] | Credit Facility Of One Hundred And Fifty Million [Member] | |
Line of Credit Facility, Expiration Date | Jul. 31, 2025 |
Line of Credit Facility, Maximum Borrowing Capacity | $ 150 |
Line of Credit Facility, Interest Rate During Period | 6.58% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | 0 |
Entergy Mississippi [Member] | Credit Facility of Sixty Five Million [Member] | |
Letters of credit posted to cover financial transmission right exposure | $ 0.3 |
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2028 |
Line of Credit Facility, Maximum Borrowing Capacity | $ 150 |
Line of Credit Facility, Interest Rate During Period | 6.71% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | 1.1 |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 30 |
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2024 |
Line of Credit Facility, Maximum Borrowing Capacity | $ 25 |
Line of Credit Facility, Interest Rate During Period | 7.08% |
Long-Term Line of Credit | $ 0 |
Letters of Credit Outstanding, Amount | 0 |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 10 |
Entergy Arkansas VIE [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana River Bend VIE [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana Waterford VIE [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
System Energy VIE [Member] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Revolving Credit Facilities, _6
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations (Details) | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member] | |
Uncommitted Credit Facility Maximum Borrowing Capacity | $ 25,000,000 |
Line of Credit Facility, Commitment Fee Amount | 0.0078 |
Letters Of Credit | 5,800,000 |
Entergy Arkansas [Member] | Credit Facility of Eighty Million [Member] | |
Letters of credit posted to cover financial transmission right exposure | 1,200,000 |
Entergy Louisiana [Member] | Credit Facility of One Hundred and Twenty Five Million [Member] | |
Uncommitted Credit Facility Maximum Borrowing Capacity | 125,000,000 |
Line of Credit Facility, Commitment Fee Amount | 0.0078 |
Letters Of Credit | 17,100,000 |
Entergy Louisiana [Member] | Credit Facility of Eighty Million [Member] | |
Letters of credit posted to cover financial transmission right exposure | 500,000 |
Entergy Mississippi [Member] | Credit Facility of Sixty Five Million [Member] | |
Uncommitted Credit Facility Maximum Borrowing Capacity | 65,000,000 |
Line of Credit Facility, Commitment Fee Amount | 0.0078 |
Letters Of Credit | 20,000,000 |
Letters of credit posted to cover financial transmission right exposure | 300,000 |
Non-MISO Letters Of Credit | 1,000,000 |
Entergy New Orleans [Member] | Credit Facility of Fifteen Million [Member] | |
Uncommitted Credit Facility Maximum Borrowing Capacity | 15,000,000 |
Line of Credit Facility, Commitment Fee Amount | 0.01625 |
Letters Of Credit | 500,000 |
Entergy Texas [Member] | Credit Facility of Eighty Million [Member] | |
Uncommitted Credit Facility Maximum Borrowing Capacity | 80,000,000 |
Line of Credit Facility, Commitment Fee Amount | 0.01250 |
Letters Of Credit | 76,500,000 |
Letters of credit posted to cover financial transmission right exposure | $ 100,000 |
Revolving Credit Facilities, _7
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions | Dec. 31, 2023 USD ($) |
Entergy Arkansas [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | $ 250 |
Short Term Borrowing | 145 |
Entergy Louisiana [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | 450 |
Short Term Borrowing | 156 |
Entergy Mississippi [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | 200 |
Short Term Borrowing | 74 |
Entergy New Orleans [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | 150 |
Short Term Borrowing | 22 |
Entergy Texas [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | 200 |
Short Term Borrowing | 0 |
System Energy [Member] | |
Short-term Debt [Line Items] | |
Authorized Short Term Borrowings | 200 |
Short Term Borrowing | $ 12 |
Revolving Credit Facilities, _8
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Entergy Arkansas VIE [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Arkansas VIE [Member] | Credit Facility of Eighty Million [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Current Borrowing Capacity | $ 80 |
Weighted Average Interest Rate on Borrowings | 6.10% |
Long-Term Line of Credit | $ 70.2 |
System Energy VIE [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
System Energy VIE [Member] | Credit Facility of One Hundred and Twenty Million [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Current Borrowing Capacity | $ 120 |
Weighted Average Interest Rate on Borrowings | 5.91% |
Long-Term Line of Credit | $ 21.5 |
Entergy Louisiana Waterford VIE [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana Waterford VIE [Member] | Credit Facility of One Hundred and Five Million [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Current Borrowing Capacity | $ 105 |
Weighted Average Interest Rate on Borrowings | 6.07% |
Long-Term Line of Credit | $ 29.5 |
Entergy Louisiana River Bend VIE [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana River Bend VIE [Member] | Credit Facility of One Hundred and Five Million [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Current Borrowing Capacity | $ 105 |
Weighted Average Interest Rate on Borrowings | 6.17% |
Long-Term Line of Credit | $ 46.6 |
Revolving Credit Facilities, _9
Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Notes Payable By Variable Interest Entities) (Details) $ in Millions | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Entergy Arkansas VIE [Member] | |
Debt Instrument [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
System Energy VIE [Member] | |
Debt Instrument [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana River Bend VIE [Member] | |
Debt Instrument [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
Entergy Louisiana Waterford VIE [Member] | |
Debt Instrument [Line Items] | |
Line of Credit Facility, Expiration Date | Jun. 30, 2025 |
VIE Notes Payable, 2.51% Series V Due June 2027 [Member] | Entergy Louisiana River Bend VIE [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Interest Rate, Stated Percentage | 2.51% |
Notes Payable, Noncurrent | $ 70 |
VIE Notes Payable, 2.51% Series V Due June 2027 [Member] | Entergy Louisiana Waterford VIE [Member] | |
Debt Instrument [Line Items] | |
Notes Payable, Noncurrent | $ 70 |
VIE Notes Payable, 1.84% Series N Due July 2026 [Member] | Entergy Arkansas VIE [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Interest Rate, Stated Percentage | 1.84% |
Notes Payable, Noncurrent | $ 90 |
VIE Notes Payable, 2.05% Series K Due September 2027 [Member] | System Energy VIE [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Interest Rate, Stated Percentage | 2.05% |
Notes Payable, Noncurrent | $ 90 |
Variable Interest Entity Notes, Five Point Nine Four Percent Series J due September 2026 [Member] | Entergy Louisiana Waterford VIE [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Interest Rate, Stated Percentage | 5.94% |
Long - Term Debt (Narrative) (D
Long - Term Debt (Narrative) (Details) - USD ($) $ in Thousands | 1 Months Ended | 12 Months Ended | |||||||||||
Jan. 31, 2022 | May 31, 2015 | Sep. 30, 2009 | Apr. 30, 2007 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2023 | Apr. 30, 2022 | Jul. 31, 2015 | Sep. 30, 2011 | Nov. 30, 2009 | Jun. 30, 2007 | Dec. 31, 1988 | |
Debt Instrument [Line Items] | |||||||||||||
Long-Term Debt, Maturity, Year One | $ 2,100,275 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 1,546,940 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 2,375,720 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 916,965 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 2,195,627 | ||||||||||||
System Energy [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Long-Term Debt, Maturity, Year One | 0 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 221,500 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 0 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 90,000 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 325,000 | ||||||||||||
Entergy Arkansas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Long-Term Debt, Maturity, Year One | 375,000 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 70,200 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 690,000 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 0 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 350,000 | ||||||||||||
Entergy Louisiana [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Long-Term Debt, Maturity, Year One | 1,400,000 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 376,100 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 720,000 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 520,000 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 425,000 | ||||||||||||
Entergy New Orleans [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Up front financing costs associated with securitization | $ 3,000 | ||||||||||||
Amount of Hurricane Issac storm cost to be recovered through securitization | 31,800 | ||||||||||||
Replenishment amount for storm reserve spending | $ 63,900 | ||||||||||||
Long-Term Debt, Maturity, Year One | 86,275 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 79,140 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 85,720 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 6,965 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 719 | ||||||||||||
Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Long-Term Debt, Maturity, Year One | 0 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 0 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 130,000 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 150,000 | ||||||||||||
Long-Term Debt, Maturity, Year Five | $ 69,908 | ||||||||||||
Hurricane Ike And Hurricane Gustav [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Amount of securitization bonds authorized to be issued for restoration costs | $ 566,400 | ||||||||||||
Debt Instrument, Face Amount | $ 545,900 | ||||||||||||
Repayments of Debt | $ 54,300 | ||||||||||||
Hurricanes Laura and Delta and Winter Storm Uri [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Amount of securitization bonds authorized to be issued for restoration costs | $ 242,900 | ||||||||||||
Hurricane Harvey [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Regulatory Asset | $ 13,300 | ||||||||||||
Hurricane Rita [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Amount of securitization bonds authorized to be issued for restoration costs | $ 353,000 | ||||||||||||
Debt Instrument, Face Amount | $ 329,500 | ||||||||||||
Amount of securitization bonds authorized to be issued for transaction costs | 6,000 | ||||||||||||
Deferred Income Tax Expense (Benefit) | $ 32,000 | ||||||||||||
Repayments of Debt | $ 17,500 | ||||||||||||
Mortgage Bonds 4.0% Series Due March 2029 [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||||||||||||
Long-Term Debt, Gross | 300,000 | $ 300,000 | |||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||||||||||||
Mortgage Bonds 4.5% Series Due March 2039 [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 4.50% | ||||||||||||
Long-Term Debt, Gross | 400,000 | $ 400,000 | |||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 4.50% | ||||||||||||
Tranche A One Two Point Six Seven Percent Due June Two Thousand Twenty Seven [Member] | Entergy New Orleans [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.67% | ||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.67% | ||||||||||||
Debt Instrument, Face Amount | $ 98,700 | ||||||||||||
Long-Term Debt, Maturity, Year One | $ 6,200 | ||||||||||||
Securitization Bonds 3.051% Series Senior Secured Due December 2028 [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.051% | 3.051% | |||||||||||
Long-Term Debt, Gross | 87,743 | $ 69,908 | |||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.051% | 3.051% | |||||||||||
Debt Instrument, Face Amount | $ 100,000 | ||||||||||||
Long-Term Debt, Maturity, Year One | $ 18,300 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 18,800 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 19,400 | ||||||||||||
Long-Term Debt, Maturity, Year Four | $ 13,400 | ||||||||||||
Securitization Bonds 3.697% Series Senior Secured Due December 2036 [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.697% | 3.697% | |||||||||||
Long-Term Debt, Gross | $ 190,850 | $ 190,850 | |||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.697% | 3.697% | |||||||||||
Debt Instrument, Face Amount | $ 190,850 | ||||||||||||
Long-Term Debt, Maturity, Year Four | $ 6,600 | ||||||||||||
Long-Term Debt, Maturity, Year Five | 20,500 | ||||||||||||
Securitization Bonds, 2.04% Series Senior Secured, Due September 2023 [Member] | Entergy Louisiana [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.04% | ||||||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.04% | ||||||||||||
Debt Instrument, Face Amount | $ 207,200 | ||||||||||||
Repayments of Debt | $ 11,000 | ||||||||||||
Aggregate Senior secured restoration bonds (securitization bonds) [Member] | Entergy Texas [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Debt Instrument, Face Amount | $ 290,850 | ||||||||||||
Grand Gulf [Member] | System Energy [Member] | |||||||||||||
Debt Instrument [Line Items] | |||||||||||||
Sale Leaseback Transaction, Net Book Value | $ 500,000 | ||||||||||||
Long-Term Debt, Maturity, Year One | 17,188 | ||||||||||||
Long-Term Debt, Maturity, Year Two | 17,188 | ||||||||||||
Long-Term Debt, Maturity, Year Three | 17,188 | ||||||||||||
Long-Term Debt, Maturity, Year Four | 17,188 | ||||||||||||
Long-Term Debt, Maturity, Year Five | $ 17,188 |
Long - Term Debt (Schedule Of L
Long - Term Debt (Schedule Of Long-term Debt Instruments) (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 | Apr. 30, 2022 |
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | $ (11,638) | $ 960 | |
Unamortized Debt Issuance Expense | (171,475) | (173,464) | |
Other Long-Term Debt | 5,420 | 5,474 | |
Long-Term Debt | 25,107,896 | 25,932,549 | |
Long-Term Debt, Current Maturities | 2,099,057 | 2,309,037 | |
Long-Term Debt, Excluding Current Maturities | 23,008,839 | 23,623,512 | |
Long-Term Debt, Fair Value | 22,489,174 | 22,573,837 | |
Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | 5,546 | 5,803 | |
Unamortized Debt Issuance Expense | (21,036) | (19,707) | |
Long-Term Debt | 2,229,510 | 2,331,096 | |
Long-Term Debt, Current Maturities | 100,000 | 400,000 | |
Long-Term Debt, Excluding Current Maturities | 2,129,510 | 1,931,096 | |
Long-Term Debt, Fair Value | 1,969,334 | 1,987,154 | |
Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | 7,508 | 12,513 | |
Unamortized Debt Issuance Expense | (36,711) | (33,009) | |
Other Long-Term Debt | 1,932 | 1,952 | |
Long-Term Debt | 4,673,080 | 4,166,500 | |
Long-Term Debt, Current Maturities | 375,000 | 290,000 | |
Long-Term Debt, Excluding Current Maturities | 4,298,080 | 3,876,500 | |
Long-Term Debt, Fair Value | 4,166,941 | 3,538,930 | |
Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | (6,478) | (8,482) | |
Unamortized Debt Issuance Expense | (56,101) | (63,698) | |
Other Long-Term Debt | 3,488 | 3,522 | |
Long-Term Debt | 9,420,689 | 10,698,922 | |
Long-Term Debt, Current Maturities | 1,400,000 | 1,010,000 | |
Long-Term Debt, Excluding Current Maturities | 8,020,689 | 9,688,922 | |
Long-Term Debt, Fair Value | 8,414,512 | 9,444,665 | |
Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | (6) | (25) | |
Unamortized Debt Issuance Expense | (7,068) | (7,698) | |
Long-Term Debt | 677,450 | 775,632 | |
Long-Term Debt, Current Maturities | 85,000 | 170,000 | |
Long-Term Debt, Excluding Current Maturities | 584,171 | 596,047 | |
Long term debt excluding current maturities, including long term payable due associated company | 591,175 | 604,326 | |
Long-Term Debt, Fair Value | 602,716 | 707,872 | |
Long-term debt and notes payable related parties, current | 86,275 | 171,306 | |
Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | 10,199 | 11,528 | |
Unamortized Debt Issuance Expense | (25,865) | (24,208) | |
Long-Term Debt | 3,225,092 | 2,895,913 | |
Long-Term Debt, Current Maturities | 0 | 0 | |
Long-Term Debt, Excluding Current Maturities | 3,225,092 | 2,895,913 | |
Long-Term Debt, Fair Value | 2,936,130 | 2,485,705 | |
System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Unamortized Discount (Premium), Net | (10,451) | (50) | |
Unamortized Debt Issuance Expense | (5,545) | (2,637) | |
Long-Term Debt | 738,459 | 777,905 | |
Long-Term Debt, Current Maturities | 57 | 300,037 | |
Long-Term Debt, Excluding Current Maturities | 738,402 | 477,868 | |
Long-Term Debt, Fair Value | $ 696,168 | 702,473 | |
Mortgage Bonds Range One [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 3.05% | ||
Long-Term Debt, Gross | $ 4,668,000 | $ 6,808,000 | |
Mortgage Bonds Range One [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0.95% | 0.62% | |
Mortgage Bonds Range One [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | 5.59% | |
Mortgage Bonds Range Two [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 2.88% | ||
Long-Term Debt, Gross | $ 3,590,000 | $ 3,265,000 | |
Mortgage Bonds Range Two [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.60% | 1.60% | |
Mortgage Bonds Range Two [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6% | 4.19% | |
Mortgage Bonds Range Three [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 4.12% | ||
Long-Term Debt, Gross | $ 3,122,000 | $ 2,097,000 | |
Mortgage Bonds Range Three [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.55% | 2.55% | |
Mortgage Bonds Range Three [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.30% | 4.52% | |
Mortgage Bonds Range Four [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 4.22% | ||
Long-Term Debt, Gross | $ 8,355,000 | $ 8,005,000 | |
Mortgage Bonds Range Four [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.65% | 2.65% | |
Mortgage Bonds Range Four [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.80% | 5.50% | |
Mortgage Bonds 2.40% Series Due October 2026 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.40% | ||
Long-Term Debt, Gross | $ 400,000 | $ 400,000 | |
Mortgage Bonds 2.85% Series Due June 2028 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.85% | ||
Long-Term Debt, Gross | $ 375,000 | 375,000 | |
Mortgage Bonds 4.52% Series Due December 2038 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.52% | ||
Long-Term Debt, Gross | $ 55,000 | 55,000 | |
Mortgage Bonds 3.85% Series Due June 2049 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.85% | ||
Long-Term Debt, Gross | $ 435,000 | 435,000 | |
Mortgage Bonds 3.05% Series Due June 2031 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.05% | ||
Long-Term Debt, Gross | $ 325,000 | 325,000 | |
Mortgage Bonds 4.00% Series Due March 2033 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||
Long-Term Debt, Gross | $ 750,000 | $ 750,000 | |
Mortgage Bonds 3.05% Series Due June 2023 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.05% | ||
Long-Term Debt, Gross | 0 | $ 250,000 | |
Mortgage Bonds 3.10% Series Due July 2023 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.10% | ||
Long-Term Debt, Gross | $ 0 | $ 250,000 | |
Mortgage Bonds 3.12% Series Due September 2027 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.12% | ||
Long-Term Debt, Gross | $ 450,000 | 450,000 | |
Mortgage Bonds 3.25% Series Due April 2028 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.25% | ||
Long-Term Debt, Gross | $ 425,000 | 425,000 | |
Mortgage Bonds 3.25% Series Due December 2027 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.25% | ||
Long-Term Debt, Gross | $ 150,000 | 150,000 | |
Mortgage Bonds 3.5% Series Due April 2026 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | ||
Long-Term Debt, Gross | $ 600,000 | 600,000 | |
Mortgage Bonds 4.00% Series Due June 2028 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||
Long-Term Debt, Gross | $ 350,000 | 350,000 | |
Mortgage Bonds 3.75% Series Due July 2024 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.75% | ||
Long-Term Debt, Gross | $ 100,000 | 100,000 | |
Mortgage Bonds 3.70% Series Due June 2024 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.70% | ||
Long-Term Debt, Gross | $ 375,000 | 375,000 | |
Mortgage Bonds 3.78% Series Due April 2025 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.78% | ||
Long-Term Debt, Gross | $ 110,000 | 110,000 | |
Mortgage Bonds 3.78% Series Due April 2025 (Legacy) [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.78% | ||
Long-Term Debt, Gross | $ 190,000 | $ 190,000 | |
Mortgage Bonds 3.90% Series Due July 2023 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.90% | ||
Long-Term Debt, Gross | $ 0 | $ 100,000 | |
Mortgage Bonds 4.0% Series Due June 2026 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||
Long-Term Debt, Gross | $ 85,000 | 85,000 | |
Mortgage Bonds 4.51% Series Due September 2033 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.51% | ||
Long-Term Debt, Gross | $ 60,000 | $ 60,000 | |
Mortgage Bonds 4.05% Series Due September 2023 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.05% | ||
Long-Term Debt, Gross | $ 0 | $ 325,000 | |
Mortgage Bonds 4.90% Series Due October 2066 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.90% | ||
Long-Term Debt, Gross | $ 260,000 | $ 260,000 | |
Mortgage Bonds 4.10% Series Due April 2023 [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.10% | ||
Long-Term Debt, Gross | $ 0 | $ 250,000 | |
Mortgage Bonds 3.45% Series Due December 2027 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.45% | ||
Long-Term Debt, Gross | $ 150,000 | 150,000 | |
Mortgage Bonds 4.0% Series Due March 2029 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4% | ||
Long-Term Debt, Gross | $ 300,000 | 300,000 | |
Mortgage Bonds 4.5% Series Due March 2039 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.50% | ||
Long-Term Debt, Gross | $ 400,000 | 400,000 | |
Mortgage Bonds 4.44% Series Due January 2026 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.44% | ||
Long-Term Debt, Gross | $ 250,000 | 250,000 | |
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.875% | ||
Long-Term Debt, Gross | $ 410,000 | 410,000 | |
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.875% | ||
Long-Term Debt, Gross | $ 270,000 | 270,000 | |
Mortgage Bonds 4.95% Series Due December 2044 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.95% | ||
Long-Term Debt, Gross | $ 250,000 | 250,000 | |
Mortgage Bonds 4.20% Series Due April 2049 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.20% | ||
Long-Term Debt, Gross | $ 550,000 | 550,000 | |
Mortgage Bonds 4.95% Series Due January 2045 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.95% | ||
Long-Term Debt, Gross | $ 450,000 | 450,000 | |
Mortgage Bonds 4.20% Series Due September 2048 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.20% | ||
Long-Term Debt, Gross | $ 900,000 | 900,000 | |
Mortgage Bonds 4.20% Series due April 2050 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.20% | ||
Long-Term Debt, Gross | $ 525,000 | 525,000 | |
Mortgage Bonds 5% Series Due July 2044 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5% | ||
Long-Term Debt, Gross | $ 170,000 | 170,000 | |
Mortgage Bonds 5.0% Series Due December 2052 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5% | ||
Long-Term Debt, Gross | $ 30,000 | 30,000 | |
Mortgage Bonds 5.15% Series Due June 2045 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.15% | ||
Long-Term Debt, Gross | $ 250,000 | 250,000 | |
Mortgage Bonds 3.55% Series Due September 2049 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.55% | ||
Long-Term Debt, Gross | $ 475,000 | 475,000 | |
Mortgage Bonds 5.40% Series Due November 2024 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | ||
Long-Term Debt, Gross | $ 400,000 | 400,000 | |
Mortgage Bonds 5.50% Series Due April 2066 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.50% | ||
Long-Term Debt, Gross | $ 110,000 | $ 110,000 | |
Mortgage Bonds 5.59% Series Due October 2024 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.59% | ||
Long-Term Debt, Gross | 0 | $ 300,000 | |
Mortgage Bonds [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 2,245,000 | 2,195,000 | |
Mortgage Bonds [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 4,335,000 | 3,860,000 | |
Mortgage Bonds [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 9,065,000 | 10,355,000 | |
Mortgage Bonds [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 585,000 | 685,000 | |
Mortgage Bonds [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 2,980,000 | 2,630,000 | |
Mortgage Bonds [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 525,000 | 450,000 | |
Governmental Bonds Range One [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 2.43% | ||
Long-Term Debt, Gross | $ 282,375 | $ 282,375 | |
Governmental Bonds Range One [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2% | 2% | |
Governmental Bonds Range One [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.50% | 2.50% | |
Governmental Bonds [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 198,680 | $ 198,680 | |
Governmental Bonds [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 83,695 | 83,695 | |
Securitization Bonds Range One [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 3.61% | ||
Long-Term Debt, Gross | $ 267,003 | $ 297,363 | |
Securitization Bonds Range One [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.67% | 2.67% | |
Securitization Bonds Range One [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.697% | 3.697% | |
Variable Interest Entities Notes Payable Range One [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 2.85% | ||
Long-Term Debt, Gross | $ 320,000 | $ 310,000 | |
Variable Interest Entities Notes Payable Range One [Member] | Minimum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.84% | 1.84% | |
Variable Interest Entities Notes Payable Range One [Member] | Maximum [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.94% | 3.22% | |
VIE Notes Payable, 3.17% Series M Due December 2023 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.17% | ||
Long-Term Debt, Gross | $ 0 | $ 40,000 | |
VIE Notes Payable, 3.22% Series I Due December 2023 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.22% | ||
Long-Term Debt, Gross | 0 | $ 20,000 | |
Variable Interest Entity Notes Payable and Credit Facilities [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 160,200 | 130,000 | |
Variable Interest Entity Notes Payable and Credit Facilities [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 216,100 | 163,900 | |
Variable Interest Entity Notes Payable and Credit Facilities [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 111,500 | 162,600 | |
Securitization Bonds 2.67% Series Senior Secured Due June 2027 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.67% | ||
Long-Term Debt, Gross | $ 6,245 | 18,770 | |
Securitization Bonds [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 6,245 | 18,770 | |
Securitization Bonds [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 260,758 | $ 278,593 | |
Entergy Corporation Notes Due September 2026 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.95% | 2.95% | |
Long-Term Debt, Gross | $ 750,000 | $ 750,000 | |
Vermont Yankee Credit Facility [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6.61% | 3.19% | |
Long-Term Debt, Gross | $ 139,000 | $ 139,000 | |
Five Year Credit Facility [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 2.97% | |
Long-Term Debt, Gross | $ 0 | $ 150,000 | |
Entergy Arkansas VIE Credit Facility [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6.10% | 2.62% | |
Long-Term Debt, Gross | $ 70,200 | $ 0 | |
Entergy Louisiana River Bend VIE Credit Facility [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6.17% | 2.17% | |
Long-Term Debt, Gross | $ 46,600 | $ 13,100 | |
Entergy Louisiana Waterford VIE Credit Facility [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6.07% | 2.74% | |
Long-Term Debt, Gross | $ 29,500 | $ 60,800 | |
System Energy VIE Credit Facility [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.91% | 2.77% | |
Long-Term Debt, Gross | $ 21,500 | $ 72,600 | |
Long Term DOE Obligation [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Weighted Average Interest Rate, at Point in Time | 0% | ||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 0% | |
Long-Term Debt, Gross | $ 205,151 | $ 195,044 | |
Long Term DOE Obligation [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 205,151 | $ 195,044 | |
Grand Gulf Sale-Leaseback Obligation [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 0% | |
Long-Term Debt, Gross | $ 34,260 | $ 34,297 | |
Grand Gulf Sale-Leaseback Obligation [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | 34,260 | 34,297 | |
Payable to Entergy Louisiana due November 2035 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Long-Term Debt, Gross | $ 8,279 | $ 9,585 | |
Entergy Corporation Notes Due September 2025 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0.90% | 0.90% | |
Long-Term Debt, Gross | $ 800,000 | $ 800,000 | |
Entergy Corporation Notes Due June 2030 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.80% | 2.80% | |
Long-Term Debt, Gross | $ 600,000 | $ 600,000 | |
Entergy Corporation Notes Due June 2050 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.75% | 3.75% | |
Long-Term Debt, Gross | $ 600,000 | $ 600,000 | |
Mortgage Bonds 2.65% Series Due June 2051 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.65% | ||
Long-Term Debt, Gross | $ 675,000 | $ 675,000 | |
Mortgage Bonds 0.62% Series Due November 2023 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0.62% | ||
Long-Term Debt, Gross | $ 0 | $ 665,000 | |
Mortgage Bonds 1.60% Series Due December 2030 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.60% | ||
Long-Term Debt, Gross | $ 300,000 | 300,000 | |
Mortgage Bonds 2.90% Series Due March 2051 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.90% | ||
Long-Term Debt, Gross | $ 650,000 | 650,000 | |
VIE Notes Payable, 2.51% Series V Due June 2027 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.51% | ||
Long-Term Debt, Gross | $ 70,000 | 70,000 | |
Mortgage Bonds 3.50% Series Due June 2051 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | ||
Long-Term Debt, Gross | $ 370,000 | 370,000 | |
Mortgage Bonds 3.0% Series Due March 2025 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3% | ||
Long-Term Debt, Gross | $ 78,000 | 78,000 | |
Mortgage Bonds 3.75% Series Due March 2040 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.75% | ||
Long-Term Debt, Gross | $ 62,000 | 62,000 | |
Mortgage Bonds 1.75% Series Due March 2031 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.75% | ||
Long-Term Debt, Gross | $ 600,000 | 600,000 | |
Mortgage Bonds 2.14% Series Due December 2025 [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.14% | ||
Long-Term Debt, Gross | $ 200,000 | 200,000 | |
VIE Notes Payable, 2.05% Series K Due September 2027 [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.05% | ||
Long-Term Debt, Gross | $ 90,000 | $ 90,000 | |
Entergy Corporation Notes due June 2028 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.90% | 1.90% | |
Long-Term Debt, Gross | $ 650,000 | $ 650,000 | |
Entergy Corporation Notes due June 2031 [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.40% | 2.40% | |
Long-Term Debt, Gross | $ 650,000 | $ 650,000 | |
VIE Notes Payable, 1.84% Series N Due July 2026 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.84% | ||
Long-Term Debt, Gross | $ 90,000 | 90,000 | |
Mortgage Bonds 0.95% Series Due October 2024 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0.95% | ||
Long-Term Debt, Gross | $ 1,000,000 | $ 1,000,000 | |
2.5% Unsecured Term Loan due May 2023 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 2.50% | |
Long-Term Debt, Gross | $ 0 | $ 70,000 | |
Mortgage Bonds 2.35% Series Due June 2032 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.35% | ||
Long-Term Debt, Gross | $ 500,000 | 500,000 | |
Mortgage Bonds 3.10% Series Due June 2041 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.10% | ||
Long-Term Debt, Gross | $ 500,000 | 500,000 | |
Governmental Bonds, 2.00% Series Due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2% | ||
Long-Term Debt, Gross | $ 16,200 | 16,200 | |
Governmental Bonds, 2.50% Series Due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.50% | ||
Long-Term Debt, Gross | $ 182,480 | 182,480 | |
Mortgage Bonds 2.55% Series Due December 2033 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.55% | ||
Long-Term Debt, Gross | $ 200,000 | 200,000 | |
Mortgage Bonds 4.19% Series Due November 2031 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.19% | ||
Long-Term Debt, Gross | $ 90,000 | 90,000 | |
Mortgage Bonds 4.51% Series Due November 2036 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.51% | ||
Long-Term Debt, Gross | $ 70,000 | 70,000 | |
Mortgage Bonds 1.50% Series Due September 2026 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.50% | ||
Long-Term Debt, Gross | $ 130,000 | 130,000 | |
Governmental Bonds 2.375% Series Due June 2044, Mississippi Business Finance Corp. [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 2.375% | ||
Long-Term Debt, Gross | $ 83,695 | $ 83,695 | |
Entergy Louisiana Credit Facility [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 7.75% | |
Long-Term Debt, Gross | $ 0 | $ 50,000 | |
Mortgage Bonds 3.35% Series Due June 2052 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.35% | ||
Long-Term Debt, Gross | $ 400,000 | $ 400,000 | |
4.082% Unsecured Term Loan due December 2023 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 4.082% | |
Long-Term Debt, Gross | $ 0 | $ 150,000 | |
3.721% Term Loan due November 2023 [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 0% | 3.721% | |
Long-Term Debt, Gross | $ 0 | $ 50,000 | |
Mortgage Bonds 4.75% Series Due September 2052 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 4.75% | ||
Long-Term Debt, Gross | $ 500,000 | 500,000 | |
Mortgage Bonds 5.00% Series Due September 2052 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5% | ||
Long-Term Debt, Gross | $ 325,000 | 325,000 | |
Securitization Bonds 3.051% Series Senior Secured Due December 2028 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.051% | 3.051% | |
Long-Term Debt, Gross | $ 69,908 | 87,743 | |
Securitization Bonds 3.697% Series Senior Secured Due December 2036 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 3.697% | 3.697% | |
Long-Term Debt, Gross | $ 190,850 | $ 190,850 | |
6.25% Unsecured Term Loan due June 2024 [Member] | Entergy New Orleans [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6.25% | 0% | |
Long-Term Debt, Gross | $ 85,000 | $ 0 | |
Mortgage Bonds 5.15% Series Due January 2033 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.15% | ||
Long-Term Debt, Gross | $ 425,000 | 0 | |
Mortgage Bonds 5.30% Series Due September 2033 [Member] | Entergy Arkansas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.30% | ||
Long-Term Debt, Gross | $ 300,000 | 0 | |
VIE Notes Payable, 5.94% Series J due September 2026 [Member] | Entergy Louisiana [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.94% | ||
Long-Term Debt, Gross | $ 70,000 | 0 | |
Mortgage Bonds 5.0% Series due September 2033 [Member] | Entergy Mississippi [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5% | ||
Long-Term Debt, Gross | $ 300,000 | 0 | |
Mortgage Bonds 5.80% Series due September 2053 [Member] | Entergy Texas [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.80% | ||
Long-Term Debt, Gross | $ 350,000 | 0 | |
Mortgage Bonds 6.00% Series Due April 2028 [Member] | System Energy [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 6% | ||
Long-Term Debt, Gross | $ 325,000 | $ 0 |
Long - Term Debt (Schedule Of M
Long - Term Debt (Schedule Of Maturities Of Long-term Debt) (Details) $ in Thousands | Dec. 31, 2023 USD ($) |
Long-Term Debt, Maturity, Year One | $ 2,100,275 |
Long-Term Debt, Maturity, Year Two | 1,546,940 |
Long-Term Debt, Maturity, Year Three | 2,375,720 |
Long-Term Debt, Maturity, Year Four | 916,965 |
Long-Term Debt, Maturity, Year Five | 2,195,627 |
Entergy Arkansas [Member] | |
Long-Term Debt, Maturity, Year One | 375,000 |
Long-Term Debt, Maturity, Year Two | 70,200 |
Long-Term Debt, Maturity, Year Three | 690,000 |
Long-Term Debt, Maturity, Year Four | 0 |
Long-Term Debt, Maturity, Year Five | 350,000 |
Entergy Louisiana [Member] | |
Long-Term Debt, Maturity, Year One | 1,400,000 |
Long-Term Debt, Maturity, Year Two | 376,100 |
Long-Term Debt, Maturity, Year Three | 720,000 |
Long-Term Debt, Maturity, Year Four | 520,000 |
Long-Term Debt, Maturity, Year Five | 425,000 |
Entergy Mississippi [Member] | |
Long-Term Debt, Maturity, Year One | 100,000 |
Long-Term Debt, Maturity, Year Two | 0 |
Long-Term Debt, Maturity, Year Three | 0 |
Long-Term Debt, Maturity, Year Four | 150,000 |
Long-Term Debt, Maturity, Year Five | 375,000 |
Entergy New Orleans [Member] | |
Long-Term Debt, Maturity, Year One | 86,275 |
Long-Term Debt, Maturity, Year Two | 79,140 |
Long-Term Debt, Maturity, Year Three | 85,720 |
Long-Term Debt, Maturity, Year Four | 6,965 |
Long-Term Debt, Maturity, Year Five | 719 |
Entergy Texas [Member] | |
Long-Term Debt, Maturity, Year One | 0 |
Long-Term Debt, Maturity, Year Two | 0 |
Long-Term Debt, Maturity, Year Three | 130,000 |
Long-Term Debt, Maturity, Year Four | 150,000 |
Long-Term Debt, Maturity, Year Five | 69,908 |
System Energy [Member] | |
Long-Term Debt, Maturity, Year One | 0 |
Long-Term Debt, Maturity, Year Two | 221,500 |
Long-Term Debt, Maturity, Year Three | 0 |
Long-Term Debt, Maturity, Year Four | 90,000 |
Long-Term Debt, Maturity, Year Five | $ 325,000 |
Long - Term Debt (Schedule Of S
Long - Term Debt (Schedule Of Senior Secured Transition Bonds) (Details) - Entergy Texas [Member] - USD ($) $ in Thousands | Dec. 31, 2023 | Apr. 30, 2022 |
Securitization Bonds 3.051% Series Senior Secured Due December 2028 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 3.051% | 3.051% |
Debt Instrument, Face Amount | $ 100,000 | |
Securitization Bonds 3.697% Series Senior Secured Due December 2036 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 3.697% | 3.697% |
Debt Instrument, Face Amount | $ 190,850 | |
Aggregate Senior secured restoration bonds (securitization bonds) [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Face Amount | $ 290,850 |
Long - Term Debt Present Value
Long - Term Debt Present Value of Future Minimum Lease Payments (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Long-Term Debt, Maturity, Year One | $ 2,100,275 | ||
Long-Term Debt, Maturity, Year Two | 1,546,940 | ||
Long-Term Debt, Maturity, Year Three | 2,375,720 | ||
Long-Term Debt, Maturity, Year Four | 916,965 | ||
Long-Term Debt, Maturity, Year Five | 2,195,627 | ||
Long-Term Debt, Fair Value | 22,489,174 | $ 22,573,837 | |
Interest Expense, Debt | 1,046,164 | 940,060 | $ 863,712 |
Long-Term Debt | 25,107,896 | 25,932,549 | |
System Energy [Member] | |||
Long-Term Debt, Maturity, Year One | 0 | ||
Long-Term Debt, Maturity, Year Two | 221,500 | ||
Long-Term Debt, Maturity, Year Three | 0 | ||
Long-Term Debt, Maturity, Year Four | 90,000 | ||
Long-Term Debt, Maturity, Year Five | 325,000 | ||
Long-Term Debt, Fair Value | 696,168 | 702,473 | |
Interest Expense, Debt | 48,416 | 37,381 | $ 38,393 |
Long-Term Debt | 738,459 | $ 777,905 | |
Grand Gulf [Member] | System Energy [Member] | |||
Long-Term Debt, Maturity, Year One | 17,188 | ||
Long-Term Debt, Maturity, Year Two | 17,188 | ||
Long-Term Debt, Maturity, Year Three | 17,188 | ||
Long-Term Debt, Maturity, Year Four | 17,188 | ||
Long-Term Debt, Maturity, Year Five | 17,188 | ||
Long-Term Debt, Maturity, after Year Five | 137,500 | ||
Long-Term Debt, Fair Value | 223,440 | ||
Interest Expense, Debt | 189,180 | ||
Long-Term Debt | $ 34,260 |
Preferred Equity (Narratives) (
Preferred Equity (Narratives) (Details) - USD ($) | 1 Months Ended | 6 Months Ended | 12 Months Ended | |||||||||||
Mar. 31, 2023 | May 31, 2022 | Nov. 30, 2021 | Sep. 30, 2019 | Nov. 30, 2018 | Nov. 30, 2017 | Oct. 31, 2015 | Dec. 31, 2013 | Jun. 30, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | May 01, 2021 | Apr. 30, 2021 | |
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Value, Issued | $ 0 | $ 0 | ||||||||||||
Temporary Equity, Shares Authorized | 450,000 | 450,000 | ||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 1,768,000 | $ 9,438,000 | $ 3,438,000 | |||||||||||
Equity, Attributable to Noncontrolling Interest | $ 120,459,000 | $ 97,907,000 | ||||||||||||
Preferred Stock, Shares Authorized | 1,000,000 | 1,000,000 | 1,000,000 | |||||||||||
Common Stock, Shares Authorized | 499,000,000 | 499,000,000 | 499,000,000 | 500,000,000 | ||||||||||
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 | $ 0.01 | |||||||||||
Preferred Stock, Shares Issued | $ 0 | $ 0 | $ 0 | |||||||||||
Entergy Arkansas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 21,599,000 | $ 27,825,000 | ||||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||||
Entergy Arkansas [Member] | AR Searcy Partnership, LLC [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 21,599,000 | $ 27,825,000 | ||||||||||||
Entergy Texas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 38,750,000 | $ 38,750,000 | ||||||||||||
Preferred Stock, Shares Authorized | 1,550,000 | 1,550,000 | ||||||||||||
Common Stock, Shares Authorized | 200,000,000 | 200,000,000 | ||||||||||||
Entergy Louisiana [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 7.50% | 7% | ||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 45,107,000 | $ 31,735,000 | ||||||||||||
LURC's percentage of annual dividends | 1% | |||||||||||||
Entergy Louisiana's percentage of annual dividends | 99% | 99% | ||||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||||
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 30,488,000 | $ 31,735,000 | ||||||||||||
LURC's percentage of annual dividends | 1% | |||||||||||||
Entergy Louisiana's percentage of annual dividends | 99% | |||||||||||||
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 14,619,000 | 0 | ||||||||||||
LURC's percentage of annual dividends | 1% | |||||||||||||
Entergy Louisiana's percentage of annual dividends | 99% | |||||||||||||
Entergy Mississippi [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 18,753,000 | $ 3,347,000 | ||||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||||
Entergy Mississippi [Member] | MS Sunflower Partnership, LLC [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 18,753,000 | $ 3,347,000 | ||||||||||||
Preferred Stock, Eight Point Seven Five Percent, Rate [Member] | Entergy Finance Holding Inc [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 8.75% | |||||||||||||
Temporary Equity, Shares Authorized | 250,000 | 250,000 | ||||||||||||
Temporary Equity, Redemption Price Per Share | $ 100 | |||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 751,000 | |||||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 6.75% Series C [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 6.75% | |||||||||||||
Temporary Equity, Shares Authorized | 75,000 | 75,000 | ||||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 1,630,000 | |||||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 7.5% Series A [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 7.50% | |||||||||||||
Temporary Equity, Shares Authorized | 110,000 | 110,000 | ||||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 2,575,000 | |||||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 6.25% Series B [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 6.25% | |||||||||||||
Temporary Equity, Shares Authorized | 15,000 | 15,000 | ||||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 634,000 | |||||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] [Domain] | Entergy Texas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 5.375% | |||||||||||||
Temporary Equity, Shares Authorized | 1,400,000 | |||||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred stock/preferred membership interests rate | 5.10% | |||||||||||||
Temporary Equity, Shares Authorized | 150,000 | |||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 0 | $ 0 | ||||||||||||
Preferred Stock, Shares Authorized | 150,000 | 150,000 | ||||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Value, Issued | $ 35,000,000 | |||||||||||||
Preferred Stock, Liquidation Preference Per Share | $ 25 | |||||||||||||
Preferred Stock, Redemption Price Per Share | $ 0 | |||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 35,000,000 | $ 35,000,000 | ||||||||||||
Preferred Stock, Shares Authorized | 1,400,000 | 1,400,000 | ||||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | On or after October 15, 2024 [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Redemption Price Per Share | $ 25 | |||||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Value, Issued | $ 3,750,000 | |||||||||||||
Preferred Stock, Liquidation Preference Per Share | $ 25 | |||||||||||||
Preferred Stock, Redemption Price Per Share | $ 25.50 | |||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 3,750,000 | $ 3,750,000 | ||||||||||||
Preferred Stock, Shares Authorized | 150,000 | 150,000 | ||||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | Prior to November 1, 2026 [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Redemption Price Per Share | $ 25.50 | |||||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | On or after November 1, 2026 [Member] | ||||||||||||||
Preferred Equity [Line Items] | ||||||||||||||
Preferred Stock, Redemption Price Per Share | $ 25 |
Preferred Equity (Schedule Of N
Preferred Equity (Schedule Of Number Of Shares And Units Authorized And Outstanding And Dollar Value Of Preferred Stock) (Details) - USD ($) | 1 Months Ended | 12 Months Ended | ||||||||||
Mar. 31, 2023 | May 31, 2022 | Nov. 30, 2021 | Sep. 30, 2019 | Nov. 30, 2018 | Nov. 30, 2017 | Oct. 31, 2015 | Dec. 31, 2013 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | May 01, 2021 | |
Temporary Equity, Shares Authorized | 450,000 | 450,000 | ||||||||||
Temporary Equity, Shares Outstanding | 450,000 | 450,000 | ||||||||||
Equity, Attributable to Noncontrolling Interest | $ 120,459,000 | $ 97,907,000 | ||||||||||
Temporary Equity, Carrying Amount, Attributable to Parent | $ 219,410,000 | $ 219,410,000 | ||||||||||
Preferred stock or preferred membership interests without sinking fund, Shares Authorized | 2,000,000 | 2,000,000 | ||||||||||
Total preferred stock or preferred membership interests without sinking fund, Shares Outstanding | 1,850,000 | 1,850,000 | ||||||||||
Preferred Stock, Value, Issued | $ 0 | $ 0 | ||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | 1,768,000 | 9,438,000 | $ 3,438,000 | |||||||||
Total preferred stock or preferred membership interests without sinking fund | $ 339,869,000 | $ 317,317,000 | ||||||||||
Preferred Stock, Shares Authorized | 1,000,000 | 1,000,000 | 1,000,000 | |||||||||
Subsidiaries | ||||||||||||
Preferred Stock, Shares Outstanding | 1,400,000 | 1,400,000 | ||||||||||
Preferred Stock, Shares Authorized | 1,550,000 | 1,550,000 | ||||||||||
Entergy Louisiana [Member] | ||||||||||||
Preferred Stock, Dividend Rate, Percentage | 7.50% | 7% | ||||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | ||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||
Entergy Louisiana [Member] | Noncontrolling Interest [Member] | ||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 45,107,000 | $ 31,735,000 | ||||||||||
Entergy Texas [Member] | ||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 38,750,000 | $ 38,750,000 | ||||||||||
Preferred Stock, Shares Outstanding | 1,550,000 | 1,550,000 | ||||||||||
Preferred Stock, Shares Authorized | 1,550,000 | 1,550,000 | ||||||||||
Preferred Stock, Par or Stated Value Per Share | $ 25 | |||||||||||
Entergy Mississippi [Member] | ||||||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | ||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||
Entergy Mississippi [Member] | Noncontrolling Interest [Member] | ||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 18,753,000 | $ 3,347,000 | ||||||||||
Entergy Arkansas [Member] | ||||||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | ||||||||||
Preferred Stock, Shares Authorized | 0 | 0 | ||||||||||
Entergy Arkansas [Member] | Noncontrolling Interest [Member] | ||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 21,599,000 | $ 27,825,000 | ||||||||||
Preferred Stock, Eight Point Seven Five Percent, Rate [Member] | Entergy Finance Holding Inc [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 250,000 | 250,000 | ||||||||||
Temporary Equity, Shares Outstanding | 250,000 | 250,000 | ||||||||||
Temporary Equity, Carrying Amount, Attributable to Parent | $ 24,249,000 | $ 24,249,000 | ||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 751,000 | |||||||||||
Preferred Stock, Dividend Rate, Percentage | 8.75% | |||||||||||
Temporary Equity, Redemption Price Per Share | $ 100 | |||||||||||
Temporary Equity, Shares Issued | 250,000 | |||||||||||
Temporary Equity, Par or Stated Value Per Share | $ 100 | |||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 7.5% Series A [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 110,000 | 110,000 | ||||||||||
Temporary Equity, Shares Outstanding | 110,000 | 110,000 | ||||||||||
Temporary Equity, Carrying Amount, Attributable to Parent | $ 107,425,000 | $ 107,425,000 | ||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 2,575,000 | |||||||||||
Preferred Stock, Dividend Rate, Percentage | 7.50% | |||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||
Temporary Equity, Shares Issued | 110,000 | |||||||||||
Temporary Equity, Liquidation Preference Per Share | $ 1,000 | |||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 6.25% Series B [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 15,000 | 15,000 | ||||||||||
Temporary Equity, Shares Outstanding | 15,000 | 15,000 | ||||||||||
Temporary Equity, Carrying Amount, Attributable to Parent | $ 14,366,000 | $ 14,366,000 | ||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 634,000 | |||||||||||
Preferred Stock, Dividend Rate, Percentage | 6.25% | |||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||
Temporary Equity, Shares Issued | 15,000 | |||||||||||
Temporary Equity, Liquidation Preference Per Share | $ 1,000 | |||||||||||
Preferred Membership Interests, Cumulative $1,000 Par Value, 6.75% Series C [Member] | Entergy Utility Holding Company LLC [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 75,000 | 75,000 | ||||||||||
Temporary Equity, Shares Outstanding | 75,000 | 75,000 | ||||||||||
Temporary Equity, Carrying Amount, Attributable to Parent | $ 73,370,000 | $ 73,370,000 | ||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | $ 1,630,000 | |||||||||||
Preferred Stock, Dividend Rate, Percentage | 6.75% | |||||||||||
Temporary Equity, Redemption Price Per Share | $ 1,000 | |||||||||||
Temporary Equity, Shares Issued | 75,000 | |||||||||||
Temporary Equity, Liquidation Preference Per Share | $ 1,000 | |||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | ||||||||||||
Equity, Attributable to Noncontrolling Interest | $ 35,000,000 | $ 35,000,000 | ||||||||||
Preferred Stock, Dividend Rate, Percentage | 5.375% | |||||||||||
Preferred Stock, Shares Outstanding | 1,400,000 | 1,400,000 | ||||||||||
Preferred Stock, Shares Authorized | 1,400,000 | 1,400,000 | ||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] [Domain] | Entergy Texas [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 1,400,000 | |||||||||||
Preferred Stock, Dividend Rate, Percentage | 5.375% | |||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | ||||||||||||
Temporary Equity, Shares Authorized | 150,000 | |||||||||||
Equity, Attributable to Noncontrolling Interest | $ 0 | $ 0 | ||||||||||
Preferred Stock, Dividend Rate, Percentage | 5.10% | |||||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | ||||||||||
Preferred Stock, Shares Authorized | 150,000 | 150,000 | ||||||||||
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | ||||||||||||
Preferred Stock, Redemption Price Per Share | $ 0 | |||||||||||
Equity, Attributable to Noncontrolling Interest | $ 35,000,000 | $ 35,000,000 | ||||||||||
Preferred Stock, Value, Issued | $ 35,000,000 | |||||||||||
Preferred Stock, Shares Outstanding | 1,400,000 | 1,400,000 | ||||||||||
Preferred Stock, Shares Authorized | 1,400,000 | 1,400,000 | ||||||||||
Preferred Stock, Five Point One Zero Percent, Series B [Member] | Entergy Texas [Member] | ||||||||||||
Preferred Stock, Redemption Price Per Share | $ 25.50 | |||||||||||
Equity, Attributable to Noncontrolling Interest | $ 3,750,000 | $ 3,750,000 | ||||||||||
Preferred Stock, Value, Issued | $ 3,750,000 | |||||||||||
Preferred Stock, Shares Outstanding | 150,000 | 150,000 | ||||||||||
Preferred Stock, Shares Authorized | 150,000 | 150,000 |
Common Equity Narrative (Detail
Common Equity Narrative (Details) - USD ($) $ / shares in Units, $ in Millions | 1 Months Ended | 2 Months Ended | 12 Months Ended | ||||||||||||||||
Dec. 29, 2023 | Dec. 05, 2023 | Nov. 30, 2023 | Nov. 21, 2023 | Jun. 28, 2023 | Jun. 06, 2023 | Nov. 30, 2022 | Sep. 30, 2022 | Jun. 30, 2022 | Mar. 31, 2022 | Oct. 31, 2021 | Aug. 31, 2021 | Jun. 30, 2021 | Dec. 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | May 31, 2022 | Oct. 31, 2010 | |
Common Stock, Dividends, Per Share, Declared | $ 4.34 | $ 4.10 | $ 3.86 | ||||||||||||||||
Proceeds from Dividends Received | $ 189 | $ 301 | $ 136 | ||||||||||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,179,962 | 931,453 | 1,013,320 | ||||||||||||||||
Stock Repurchase Program, Authorized Amount | $ 500 | ||||||||||||||||||
Stock Repurchase Program, Remaining Authorized Repurchase Amount | $ 350 | $ 350 | |||||||||||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,179,962 | 931,453 | 1,013,320 | ||||||||||||||||
Equity Distribution Program [Member] | |||||||||||||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,762,709 | 1,158,917 | 1,158,917 | ||||||||||||||||
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $ 1,500 | ||||||||||||||||||
Equity Distribution Sales Agreement Increase in Aggregate Gross Sales Price | $ 2,000 | ||||||||||||||||||
Forward Sale Agreement, Aggregate Compensation to Forward Sellers | $ 2.8 | $ 0.8 | $ 0.4 | $ 0.1 | $ 1.9 | $ 2.5 | $ 1.7 | $ 0.3 | $ 1.9 | $ 0.5 | |||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,762,709 | 1,158,917 | 1,158,917 | ||||||||||||||||
Equity Distribution Program [Member] | Common Stock [Member] | |||||||||||||||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ 101.11 | $ 97.48 | $ 101.38 | $ 97.48 | $ 101.39 | $ 101.36 | $ 112.50 | $ 115.46 | $ 116.94 | $ 108.12 | $ 100.35 | $ 111.16 | $ 106.87 | ||||||
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $ 280.5 | $ 83.3 | $ 47.8 | $ 84 | $ 37.4 | $ 10.5 | $ 853.3 | $ 194.2 | $ 250.9 | $ 168 | $ 25.4 | $ 190.1 | $ 45 | ||||||
Forward Contract Indexed to Issuer's Equity, Indexed Shares | 2,753,246 | 853,117 | 365,307 | 102,995 | 1,666,172 | 2,124,086 | 1,538,010 | 250,743 | 1,692,555 | 416,853 | |||||||||
Forward Contract Indexed to Equity, Settlement, Number of Shares | 853,117 | 468,302 | 853,117 | 365,307 | 102,995 | 7,688,419 | 1,666,172 | 2,124,086 | 1,538,010 | 250,743 | 1,692,555 | 416,853 | |||||||
General Issuance Costs | $ 0.7 | 0.4 | $ 1.4 | ||||||||||||||||
Net Sales Proceeds | 200.8 | ||||||||||||||||||
Gross Sales Price | 204.2 | ||||||||||||||||||
Aggregate Compensation to Sales Agents | $ 2 | ||||||||||||||||||
Stock Issued During Period, Shares, New Issues | 0 | 0 | 1,930,330 | ||||||||||||||||
Stock Issued During Period, Shares, New Issues | 0 | 0 | 1,930,330 | ||||||||||||||||
Net Sales Proceeds | $ 200.8 | ||||||||||||||||||
Gross Sales Price | 204.2 | ||||||||||||||||||
General Issuance Costs | $ 0.7 | $ 0.4 | 1.4 | ||||||||||||||||
Aggregate Compensation to Sales Agents | $ 2 | ||||||||||||||||||
Common Stock [Member] | |||||||||||||||||||
Stock Issued During Period, Shares, New Issues | 1,321,419 | 7,688,419 | 1,930,330 | ||||||||||||||||
Stock Issued During Period, Shares, New Issues | 1,321,419 | 7,688,419 | 1,930,330 |
Common Equity Common Stock And
Common Equity Common Stock And Treasury Stock Shares Activity (Details) - shares | 12 Months Ended | |||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Common Stock And Treasury Stock [Roll Forward] | ||||
Treasury Stock, Common, Shares | 68,477,429 | |||
Common Stock, Shares, Issued | 280,975,348 | 279,653,929 | ||
Treasury Stock, Common, Shares | 68,126,778 | 68,477,429 | ||
Common Stock [Member] | ||||
Common Stock And Treasury Stock [Roll Forward] | ||||
Shares Issued, Shares, Share-Based Payment Arrangement, after Forfeiture | 0 | 0 | 0 | |
Stock issued during period shares directors plan | 0 | 0 | 0 | |
Common Stock, Shares, Issued | 280,975,348 | 279,653,929 | 271,965,510 | 270,035,180 |
Stock Issued During Period, Shares, New Issues | 1,321,419 | 7,688,419 | 1,930,330 | |
Treasury Stock, Common [Member] | ||||
Common Stock And Treasury Stock [Roll Forward] | ||||
Treasury Stock, Common, Shares | 68,477,429 | 69,312,326 | 69,790,346 | |
Shares Issued, Shares, Share-Based Payment Arrangement, after Forfeiture | (336,621) | (818,366) | (461,903) | |
Stock issued during period shares directors plan | (14,030) | (16,531) | (16,117) | |
Treasury Stock, Common, Shares | 68,126,778 | 68,477,429 | 69,312,326 | |
Stock Issued During Period, Shares, New Issues | 0 | 0 | 0 |
Common Equity Changes in Accumu
Common Equity Changes in Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | $ 29,294 | $ 140,774 | $ 116,679 |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 39,919 | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 100,855 | ||
Accumulated Other Comprehensive Income (Loss), Net of Tax | (162,460) | (191,754) | (332,528) |
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | 1,035 | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 127 | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 908 | ||
Accumulated Other Comprehensive Income (Loss), Net of Tax | 0 | (1,035) | |
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | 29,294 | 146,893 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (7,110) | 33,949 | |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 36,404 | 112,944 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax | (162,460) | (191,754) | (338,647) |
AOCI, Accumulated Gain (Loss), Debt Securities, Available-for-Sale, Parent [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | (7,154) | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 5,843 | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (12,997) | ||
Accumulated Other Comprehensive Income (Loss), Net of Tax | 0 | 7,154 | |
Entergy Louisiana [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | (572) | 47,092 | 3,951 |
Accumulated Other Comprehensive Income (Loss), Net of Tax | 54,798 | 55,370 | |
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax, Total | (572) | 47,092 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (6,175) | (995) | |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 5,603 | 48,087 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax | $ 54,798 | $ 55,370 | $ 8,278 |
Common Equity Reclassifications
Common Equity Reclassifications from Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Miscellaneous - net | $ (201,013) | $ (77,629) | $ (201,778) |
Income Tax Expense (Benefit) | (690,535) | (38,978) | 191,374 |
Consolidated net income | 2,362,310 | 1,097,138 | 1,118,719 |
Reclassification out of Accumulated Other Comprehensive Income [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Consolidated net income | 7,110 | (39,919) | |
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 0 | (161) | |
Income Tax Expense (Benefit) | 0 | (34) | |
Consolidated net income | 0 | (127) | |
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Net Periodic Pension And Other Postretirement Benefit Costs [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 13,586 | 15,337 | |
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 9,328 | (43,843) | |
Defined Benefit Plan, Amortization of Gain (Loss) | (6,590) | 33,859 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (10,848) | (25,321) | |
Income Tax Expense (Benefit) | 2,218 | (9,894) | |
Consolidated net income | 7,110 | (33,949) | |
AOCI, Accumulated Gain (Loss), Debt Securities, Available-for-Sale, Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Realized Investment Gains (Losses) | 0 | (9,245) | |
Income Tax Expense (Benefit) | 0 | (3,402) | |
Consolidated net income | 0 | (5,843) | |
Interest Rate Swap [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Miscellaneous - net | 0 | (161) | |
Entergy Louisiana [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Miscellaneous - net | (160,972) | 9,824 | (125,886) |
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 1,067,589 | 693,017 | 774,393 |
Income Tax Expense (Benefit) | (205,781) | (162,853) | 120,409 |
Consolidated net income | 1,273,370 | 855,870 | $ 653,984 |
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Net Periodic Pension And Other Postretirement Benefit Costs [Member] | |||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | |||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 3,804 | 4,630 | |
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Noncontrolling Interest | 8,450 | 1,361 | |
Defined Benefit Plan, Amortization of Gain (Loss) | 6,263 | (927) | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (1,617) | (2,342) | |
Income Tax Expense (Benefit) | 2,275 | 366 | |
Consolidated net income | $ 6,175 | $ 995 |
Commitments And Contingencies_2
Commitments And Contingencies (Narrative) (Details) | 1 Months Ended | 3 Months Ended | 12 Months Ended | 84 Months Ended | 120 Months Ended | 180 Months Ended | ||||||||||||||||||||||
Jan. 01, 2018 | Aug. 31, 2023 USD ($) | Jul. 31, 2023 USD ($) | Mar. 31, 2023 USD ($) | Oct. 31, 2021 USD ($) | Aug. 31, 2021 USD ($) | Jan. 31, 2021 USD ($) | Dec. 31, 2018 USD ($) | Dec. 31, 2017 USD ($) | Feb. 28, 2014 USD ($) | Nov. 30, 2013 USD ($) | Sep. 30, 2023 USD ($) | Dec. 31, 2024 USD ($) | Dec. 31, 2023 USD ($) reactor claim program | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | Dec. 31, 2020 | Dec. 31, 2019 | Dec. 31, 2018 USD ($) | Dec. 31, 2017 USD ($) | Dec. 31, 2016 USD ($) | Dec. 31, 2015 USD ($) | Dec. 31, 2014 USD ($) | Dec. 31, 2013 USD ($) | Dec. 31, 2031 USD ($) | Oct. 01, 2012 USD ($) | Dec. 31, 2026 USD ($) | Jan. 01, 2024 USD ($) | |
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Number of Financial Protection Programs | program | 2 | |||||||||||||||||||||||||||
Maximum Retrospective Insurance Premium Obligation Per Reactor Per Incident | $ 165,900,000 | |||||||||||||||||||||||||||
Maximum retrospective insurance premium obligation per incident | 829,600,000 | |||||||||||||||||||||||||||
Maximum retrospective premium per year per incident per nuclear power reactor | 24,700,000 | |||||||||||||||||||||||||||
Total insurance coverage available including American Nuclear Insurers coverage and Secondary Financial Protection program coverage | $ 16,300,000,000 | |||||||||||||||||||||||||||
Number Of Nuclear Reactors Included In Secondary Financial Protection Program | reactor | 95 | |||||||||||||||||||||||||||
Total secondary layer insurance coverage under Secondary Financial Protection program | $ 15,800,000,000 | |||||||||||||||||||||||||||
Maximum Recovery Nuclear Insurance Policies For Property Damage Caused By Terrorist Act | 3,240,000,000 | |||||||||||||||||||||||||||
Maximum Conventional Property Insurance Coverage On Each And Every Loss Basis | 400,000,000 | |||||||||||||||||||||||||||
Conventional Property Insurance, Minimum Value Of Assets Covered | 5,000,000 | |||||||||||||||||||||||||||
Terrorism insurance coverage for conventional property | $ 400,000,000 | |||||||||||||||||||||||||||
Spent fuel fee until the DOE complies with the Nuclear Waste Policy Act of 1982 or Congress enacts an alternative waste disposal plan | $ 0 | |||||||||||||||||||||||||||
Percentage of Weekly Indemnity Paid After Deductible Second Period has Passed | 80% | |||||||||||||||||||||||||||
Percentage of Weekly Indemnity Paid After Deductible Final Period has Passed | 80% | |||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | 21% | 35% | 35% | ||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 463,805,000 | $ (266,559,000) | $ 43,631,000 | |||||||||||||||||||||||||
Percentage of Weekly Indemnity Paid After Deductible First Period has Passed | 100% | |||||||||||||||||||||||||||
Asset Impairment Charges | $ 42,679,000 | (163,464,000) | 263,625,000 | |||||||||||||||||||||||||
Operational Perils [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Self-insured retention | 20,000,000 | |||||||||||||||||||||||||||
Earthquake and Flood [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Maximum Conventional Property Insurance Coverage On Each And Every Loss Basis | 400,000,000 | |||||||||||||||||||||||||||
Self-insured retention | 40,000,000 | |||||||||||||||||||||||||||
Named Windstorm and Associated Storm Surge [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Maximum Conventional Property Insurance Coverage On Each And Every Loss Basis | 125,000,000 | |||||||||||||||||||||||||||
Self-insured retention | 40,000,000 | |||||||||||||||||||||||||||
ANO and Grand Gulf [Member] | Flood [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Primary Insurance Layer Conditions Of Coverage | $ 500,000,000 | |||||||||||||||||||||||||||
Palisades [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Damages awarded for previously capitalized costs | $ 16,000,000 | |||||||||||||||||||||||||||
Damages awarded for previously recorded operation and maintenance | 7,000,000 | |||||||||||||||||||||||||||
Reduction of previously recorded deprecation expense | 9,000,000 | |||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | 23,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as plant | $ 16,000,000 | |||||||||||||||||||||||||||
Grand Gulf [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Ownership Percentage By Non Affiliated Company | 10% | |||||||||||||||||||||||||||
Indian Point [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Damages awarded for previously recorded operation and maintenance | $ 47,000,000 | |||||||||||||||||||||||||||
Damages awarded for previously recorded taxes other than income taxes | 4,000,000 | |||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | $ 59,000,000 | 83,000,000 | ||||||||||||||||||||||||||
Damages awarded for costs previously recorded as plant | 6,000,000 | $ 32,000,000 | ||||||||||||||||||||||||||
Damages awarded for costs previously recorded as other operation and maintenance expense | 15,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as taxes other than income taxes | 1,000,000 | |||||||||||||||||||||||||||
Proceeds from Legal Settlements | $ 40,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as spending on the asset retirement obligation | $ 18,000,000 | |||||||||||||||||||||||||||
Pilgrim [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | $ 37,600,000 | |||||||||||||||||||||||||||
Subsequent Event [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
American Nuclear Insurers public liability insurance coverage per operating reactor | $ 500,000,000 | |||||||||||||||||||||||||||
Utility [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property Insurance Deductible | $ 20,000,000 | |||||||||||||||||||||||||||
Asset Impairment Charges | 79,962,000 | 0 | 0 | |||||||||||||||||||||||||
Utility [Member] | Property Insurance [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property damage insurance limit per occurrence | 1,060,000,000 | |||||||||||||||||||||||||||
Utility [Member] | Earthquake [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Primary Insurance Layer Conditions Of Coverage | 500,000,000 | |||||||||||||||||||||||||||
Utility [Member] | Wind [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property Insurance Deductible | $ 10,000,000 | |||||||||||||||||||||||||||
Percentage of Additional Property Insurance Deductible for Loss in Excess of Deductible | 10% | |||||||||||||||||||||||||||
Utility [Member] | Asbestos Issue [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Loss Contingency, Pending Claims, Number | claim | 195 | |||||||||||||||||||||||||||
Loss Contingency, Number of Plaintiffs | claim | 345 | |||||||||||||||||||||||||||
Utility [Member] | River Bend and Waterford 3 [Member] | Flood [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property Insurance Deductible | $ 10,000,000 | |||||||||||||||||||||||||||
Percentage of Additional Property Insurance Deductible for Loss in Excess of Deductible | 10% | |||||||||||||||||||||||||||
Utility [Member] | Maximum [Member] | Wind [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property Insurance Deductible | $ 50,000,000 | |||||||||||||||||||||||||||
Utility [Member] | Maximum [Member] | River Bend and Waterford 3 [Member] | Flood [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Property Insurance Deductible | $ 50,000,000 | |||||||||||||||||||||||||||
Entergy Mississippi [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Percentage Of Capacity And Energy Agreed To Sell From Variable Interest Entity To Other Subsidiaries | 33% | |||||||||||||||||||||||||||
Average Monthly Payments Under Unit Power Sales Agreement | $ 16,300,000 | |||||||||||||||||||||||||||
Purchased Percentage Of Capacity And Energy Based On Agreement | 31.30% | |||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ (59,513,000) | 20,165,000 | 21,930,000 | |||||||||||||||||||||||||
Proceeds from Legal Settlements | $ 36,000,000 | |||||||||||||||||||||||||||
Entergy Texas [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ (20,122,000) | (30,499,000) | (28,747,000) | |||||||||||||||||||||||||
Proceeds from Legal Settlements | 33,000,000 | |||||||||||||||||||||||||||
System Energy [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Number of Nuclear Power Reactors | reactor | 1 | |||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 11,009,000 | 21,252,000 | 40,884,000 | |||||||||||||||||||||||||
Entergy New Orleans [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Maximum Conventional Property Insurance Coverage On Each And Every Loss Basis | $ 50,000,000 | |||||||||||||||||||||||||||
Percentage Of Capacity And Energy Agreed To Sell From Variable Interest Entity To Other Subsidiaries | 17% | |||||||||||||||||||||||||||
Average Monthly Payments Under Unit Power Sales Agreement | $ 8,100,000 | |||||||||||||||||||||||||||
Purchased Percentage Of Capacity And Energy Based On Agreement | 24.70% | |||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 66,022,000 | (8,639,000) | 4,985,000 | |||||||||||||||||||||||||
Proceeds from Legal Settlements | 7,000,000 | |||||||||||||||||||||||||||
Entergy Louisiana [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Payments Made Under Purchased Power Agreement | $ 100,400,000 | 117,200,000 | 128,500,000 | |||||||||||||||||||||||||
Required Energy For Production In Percentage | 94% | |||||||||||||||||||||||||||
Credit to rates agreed to by subsidiary for each year under settlement related to tax benefits from the tax treatment of Purchased Power Agreement | $ 11,000,000 | |||||||||||||||||||||||||||
Number of years for which credit to rates agreed to by subsidiary under settlement related to tax benefits from the tax treatment of Purchased Power Agreement | 10 years | |||||||||||||||||||||||||||
Number of Nuclear Power Reactors | reactor | 2 | |||||||||||||||||||||||||||
Percentage Of Capacity And Energy Agreed To Sell From Variable Interest Entity To Other Subsidiaries | 14% | |||||||||||||||||||||||||||
Average Monthly Payments Under Unit Power Sales Agreement | $ 6,700,000 | |||||||||||||||||||||||||||
Purchased Percentage Of Capacity And Energy Based On Agreement | 26.90% | |||||||||||||||||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21% | |||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 225,645,000 | (4,783,000) | (16,478,000) | |||||||||||||||||||||||||
Proceeds from Legal Settlements | $ 59,000,000 | |||||||||||||||||||||||||||
Entergy Louisiana [Member] | River Bend [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Damages awarded for previously recorded operation and maintenance | 4,000,000 | |||||||||||||||||||||||||||
Damages awarded for previously recorded nuclear fuel expense | 8,000,000 | |||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | 21,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as plant | $ 9,000,000 | |||||||||||||||||||||||||||
Entergy Louisiana [Member] | Subsequent Event [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Estimated Payments Under Purchased Power Agreement in Next Twelve Months | $ 137,400,000 | |||||||||||||||||||||||||||
Estimated Payments Under Purchased Power Agreement in Year Two and Thereafter | $ 958,800,000 | |||||||||||||||||||||||||||
Credit to rates agreed to by subsidiary for each year under settlement related to tax benefits from the tax treatment of Purchased Power Agreement | $ 20,235,000 | |||||||||||||||||||||||||||
Number of years for which credit to rates agreed to by subsidiary under settlement related to tax benefits from the tax treatment of Purchased Power Agreement | 15 years | |||||||||||||||||||||||||||
Entergy Arkansas [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Estimated Cost To Restore ANO To Service | $ 95,000,000 | |||||||||||||||||||||||||||
Proceeds From Insurance Settlement, Operating and Investing Activities | $ 50,000,000 | |||||||||||||||||||||||||||
Number of Nuclear Power Reactors | reactor | 2 | |||||||||||||||||||||||||||
Percentage Of Capacity And Energy Agreed To Sell From Variable Interest Entity To Other Subsidiaries | 36% | |||||||||||||||||||||||||||
Average Monthly Payments Under Unit Power Sales Agreement | $ 17,900,000 | |||||||||||||||||||||||||||
Purchased Percentage Of Capacity And Energy Based On Agreement | 17.10% | |||||||||||||||||||||||||||
Incremental NRC Inspection Costs | $ 53,000,000 | |||||||||||||||||||||||||||
NRC inspection and performance improvement costs | $ 7,000,000 | $ 44,000,000 | ||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | $ 21,000,000 | |||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ 240,762,000 | (264,054,000) | 21,066,000 | |||||||||||||||||||||||||
Asset Impairment Charges | $ 78,434,000 | $ 0 | $ 0 | |||||||||||||||||||||||||
Asset impairment charge for undepreciated balance in capital costs | $ 9,500,000 | |||||||||||||||||||||||||||
Entergy Arkansas [Member] | Deferred Fuel Costs [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Asset Impairment Charges | 68,900,000 | |||||||||||||||||||||||||||
Entergy Arkansas [Member] | ANO [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Deferred Fuel and Purchased Energy Costs Excluded From Revised Energy Cost Rate | $ 65,900,000 | |||||||||||||||||||||||||||
Litigation Settlement, Amount Awarded from Other Party | $ 41,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as plant | 18,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as other operation and maintenance expense | 10,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as nuclear fuel expense | 8,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as materials and supplies | 3,000,000 | |||||||||||||||||||||||||||
Damages awarded for costs previously recorded as taxes other than income taxes | $ 2,000,000 | |||||||||||||||||||||||||||
Entergy Arkansas [Member] | Utility [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Asset Impairment Charges | $ 78,000,000 | |||||||||||||||||||||||||||
Vidalia Purchased Power Agreement [Member] | ||||||||||||||||||||||||||||
Commitments And Contingencies [Line Items] | ||||||||||||||||||||||||||||
Increase (Decrease) in Regulatory Liabilities | $ (30,500,000) |
Commitments And Contingencies_3
Commitments And Contingencies (Maximum Amounts Of Possible Assessments Per Occurrence) (Details) - Insurance-related Assessments [Member] $ in Millions | Apr. 01, 2023 USD ($) |
Entergy Arkansas [Member] | |
Commitments And Contingencies [Line Items] | |
Loss Contingency, Estimate of Possible Loss | $ 19.4 |
Entergy Louisiana [Member] | |
Commitments And Contingencies [Line Items] | |
Loss Contingency, Estimate of Possible Loss | 36.6 |
Entergy Mississippi [Member] | |
Commitments And Contingencies [Line Items] | |
Loss Contingency, Estimate of Possible Loss | 0.1 |
Entergy New Orleans [Member] | |
Commitments And Contingencies [Line Items] | |
Loss Contingency, Estimate of Possible Loss | 0.1 |
System Energy [Member] | |
Commitments And Contingencies [Line Items] | |
Loss Contingency, Estimate of Possible Loss | $ 14.3 |
Asset Retirement Obligations (N
Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||
Sep. 30, 2023 | Sep. 30, 2022 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Asset Retirement Obligation | $ 4,505.8 | $ 4,271.5 | $ 4,757.1 | ||
Asset Retirement Obligation, Revision of Estimate | 14.9 | (0.5) | |||
Entergy Louisiana [Member] | |||||
Asset Retirement Obligation | 1,836.2 | 1,736.8 | 1,653.2 | ||
Asset Retirement Obligation, Revision of Estimate | 10.8 | 2.8 | |||
Entergy Louisiana [Member] | Big Cajun 2 [Member] | |||||
Asset Retirement Obligation, Revision of Estimate | $ 2.8 | ||||
Entergy Louisiana [Member] | River Bend [Member] | |||||
Asset Retirement Obligation, Revision of Estimate | $ 10.8 | ||||
System Energy [Member] | |||||
Asset Retirement Obligation | 1,084.2 | 1,042.5 | 1,007.6 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | (5.4) | |||
System Energy [Member] | Grand Gulf [Member] | |||||
Asset Retirement Obligation, Revision of Estimate | 5.4 | ||||
Entergy Arkansas [Member] | |||||
Asset Retirement Obligation | 1,560.1 | 1,472.7 | 1,390.4 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||
Entergy Mississippi [Member] | |||||
Asset Retirement Obligation | 8.2 | 7.8 | 10.3 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||
Entergy Texas [Member] | |||||
Asset Retirement Obligation | 11.7 | 11.1 | 8.5 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 2.1 | |||
Entergy Texas [Member] | Big Cajun 2 [Member] | |||||
Asset Retirement Obligation, Revision of Estimate | $ 2.1 | ||||
Entergy New Orleans [Member] | |||||
Asset Retirement Obligation | 4.6 | 0 | $ 4 | ||
Asset Retirement Obligation, Revision of Estimate | $ 4.1 | $ 0 |
Asset Retirement Obligations (D
Asset Retirement Obligations (Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates) (Details) - Removal Costs [Member] - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Entergy Arkansas [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | $ 319.7 | $ 267.1 |
Entergy Louisiana [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | 262.3 | 418.8 |
Entergy Mississippi [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | 188 | 159.4 |
Entergy New Orleans [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | 61.1 | 56.3 |
Entergy Texas [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | 77.5 | 62.9 |
System Energy [Member] | ||
Asset Retirement Obligations [Line Items] | ||
Regulatory Asset | $ 102.1 | $ 94.4 |
Asset Retirement Obligations (C
Asset Retirement Obligations (Cumulative Decommissioning And Retirement Cost Liabilities And Expenses) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | $ 4,505.8 | $ 4,271.5 | $ 4,757.1 |
Asset Retirement Obligation, Accretion Expense | 219.4 | 236 | |
Asset Retirement Obligation, Liabilities Settled | (707.8) | ||
Asset Retirement Obligation, Period Increase (Decrease) | 13.3 | ||
Asset Retirement Obligation, Revision of Estimate | 14.9 | (0.5) | |
Entergy Arkansas [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 1,560.1 | 1,472.7 | 1,390.4 |
Asset Retirement Obligation, Accretion Expense | 87.4 | 82.3 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |
Entergy Louisiana [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 1,836.2 | 1,736.8 | 1,653.2 |
Asset Retirement Obligation, Accretion Expense | 88.6 | 84.1 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 3.3 | ||
Asset Retirement Obligation, Revision of Estimate | 10.8 | 2.8 | |
Entergy Mississippi [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 8.2 | 7.8 | 10.3 |
Asset Retirement Obligation, Accretion Expense | 0.4 | 0.6 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 3.1 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |
Entergy New Orleans [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 4.6 | 0 | 4 |
Asset Retirement Obligation, Accretion Expense | 0.5 | 0.1 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 4.1 | ||
Asset Retirement Obligation, Revision of Estimate | 4.1 | 0 | |
Entergy Texas [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 11.7 | 11.1 | 8.5 |
Asset Retirement Obligation, Accretion Expense | 0.6 | 0.5 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | 2.1 | |
System Energy [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 1,084.2 | 1,042.5 | 1,007.6 |
Asset Retirement Obligation, Accretion Expense | 41.7 | 40.2 | |
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||
Asset Retirement Obligation, Revision of Estimate | $ 0 | (5.4) | |
Other [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 0.6 | 0.6 | |
Asset Retirement Obligation, Accretion Expense | 0 | ||
Asset Retirement Obligation, Liabilities Settled | 0 | ||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | ||
Big Rock Point [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 0 | 42 | |
Asset Retirement Obligation, Accretion Expense | 2 | ||
Asset Retirement Obligation, Liabilities Settled | (42.8) | ||
Asset Retirement Obligation, Period Increase (Decrease) | 1.2 | ||
Asset Retirement Obligation, Revision of Estimate | 0 | ||
Palisades [Member] | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||
Asset Retirement Obligation | 0 | $ 640.4 | |
Asset Retirement Obligation, Accretion Expense | 31 | ||
Asset Retirement Obligation, Liabilities Settled | (669.8) | ||
Asset Retirement Obligation, Period Increase (Decrease) | 1.6 | ||
Asset Retirement Obligation, Revision of Estimate | $ 0 |
Leases (Narrative) (Details)
Leases (Narrative) (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Operating Lease, Expense | $ 68,136 | $ 65,463 |
Finance Lease, Right-of-Use Asset, Amortization | 15,193 | 13,493 |
Finance Lease, Interest Expense | 3,639 | 2,702 |
Short-Term Lease, Cost | $ 5,000 | $ 5,400 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration] | Public Utilities, Property, Plant and Equipment, Plant in Service | Public Utilities, Property, Plant and Equipment, Plant in Service |
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration] | Public Utilities, Property, Plant and Equipment, Plant in Service | Public Utilities, Property, Plant and Equipment, Plant in Service |
Entergy Arkansas [Member] | ||
Operating Lease, Right-of-Use Asset | $ 61,718 | $ 56,000 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 17,622 | 13,493 |
Operating Lease, Expense | 17,065 | 15,435 |
Finance Lease, Right-of-Use Asset, Amortization | 3,633 | 3,048 |
Finance Lease, Interest Expense | 545 | 402 |
Short-Term Lease, Cost | 1,700 | 1,700 |
Entergy Louisiana [Member] | ||
Operating Lease, Right-of-Use Asset | 54,047 | 46,137 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 21,438 | 18,540 |
Operating Lease, Expense | 16,906 | 15,016 |
Finance Lease, Right-of-Use Asset, Amortization | 4,835 | 4,259 |
Finance Lease, Interest Expense | 729 | 592 |
Short-Term Lease, Cost | 1,600 | 1,800 |
Entergy Mississippi [Member] | ||
Operating Lease, Right-of-Use Asset | 25,470 | 23,624 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 22,661 | 8,578 |
Operating Lease, Expense | 7,837 | 7,510 |
Finance Lease, Right-of-Use Asset, Amortization | 2,227 | 1,962 |
Finance Lease, Interest Expense | 973 | 261 |
Short-Term Lease, Cost | 1,100 | 900 |
Entergy New Orleans [Member] | ||
Operating Lease, Right-of-Use Asset | 6,119 | 5,906 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 4,779 | 4,342 |
Operating Lease, Expense | 1,912 | 1,755 |
Finance Lease, Right-of-Use Asset, Amortization | 1,025 | 906 |
Finance Lease, Interest Expense | 150 | 134 |
Short-Term Lease, Cost | 100 | 200 |
Entergy Texas [Member] | ||
Operating Lease, Right-of-Use Asset | 21,321 | 17,076 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 8,714 | 8,094 |
Operating Lease, Expense | 7,290 | 5,624 |
Finance Lease, Right-of-Use Asset, Amortization | 1,786 | 1,629 |
Finance Lease, Interest Expense | 284 | 230 |
Short-Term Lease, Cost | $ 400 | $ 800 |
Leases Lease, Cost (Details)
Leases Lease, Cost (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Operating Lease, Expense | $ 68,136 | $ 65,463 |
Finance Lease, Right-of-Use Asset, Amortization | 15,193 | 13,493 |
Finance Lease, Interest Expense | 3,639 | 2,702 |
Short-Term Lease, Cost | 5,000 | 5,400 |
Entergy Louisiana [Member] | ||
Operating Lease, Expense | 16,906 | 15,016 |
Finance Lease, Right-of-Use Asset, Amortization | 4,835 | 4,259 |
Finance Lease, Interest Expense | 729 | 592 |
Short-Term Lease, Cost | 1,600 | 1,800 |
Entergy Mississippi [Member] | ||
Operating Lease, Expense | 7,837 | 7,510 |
Finance Lease, Right-of-Use Asset, Amortization | 2,227 | 1,962 |
Finance Lease, Interest Expense | 973 | 261 |
Short-Term Lease, Cost | 1,100 | 900 |
Entergy New Orleans [Member] | ||
Operating Lease, Expense | 1,912 | 1,755 |
Finance Lease, Right-of-Use Asset, Amortization | 1,025 | 906 |
Finance Lease, Interest Expense | 150 | 134 |
Short-Term Lease, Cost | 100 | 200 |
Entergy Texas [Member] | ||
Operating Lease, Expense | 7,290 | 5,624 |
Finance Lease, Right-of-Use Asset, Amortization | 1,786 | 1,629 |
Finance Lease, Interest Expense | 284 | 230 |
Short-Term Lease, Cost | 400 | 800 |
Entergy Arkansas [Member] | ||
Operating Lease, Expense | 17,065 | 15,435 |
Finance Lease, Right-of-Use Asset, Amortization | 3,633 | 3,048 |
Finance Lease, Interest Expense | 545 | 402 |
Short-Term Lease, Cost | $ 1,700 | $ 1,700 |
Leases Lease, Assets (Details)
Leases Lease, Assets (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Entergy Louisiana [Member] | ||
Operating Lease, Right-of-Use Asset | $ 54,047 | $ 46,137 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 21,438 | 18,540 |
Entergy Mississippi [Member] | ||
Operating Lease, Right-of-Use Asset | 25,470 | 23,624 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 22,661 | 8,578 |
Entergy New Orleans [Member] | ||
Operating Lease, Right-of-Use Asset | 6,119 | 5,906 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 4,779 | 4,342 |
Entergy Texas [Member] | ||
Operating Lease, Right-of-Use Asset | 21,321 | 17,076 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | 8,714 | 8,094 |
Entergy Arkansas [Member] | ||
Operating Lease, Right-of-Use Asset | 61,718 | 56,000 |
Finance Lease, Right-of-Use Asset, after Accumulated Amortization | $ 17,622 | $ 13,493 |
Leases Lease, Liabilities (Deta
Leases Lease, Liabilities (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 5 months 15 days | 4 years 3 months 25 days |
Finance Lease, Weighted Average Remaining Lease Term | 8 years 7 months 9 days | 5 years 7 months 17 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.10% | 3.61% |
Finance Lease, Weighted Average Discount Rate, Percent | 4.64% | 3.95% |
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current |
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current |
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration] | Deferred Credits and Other Liabilities | Deferred Credits and Other Liabilities |
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration] | Deferred Credits and Other Liabilities | Deferred Credits and Other Liabilities |
Entergy Louisiana [Member] | ||
Operating Lease, Liability, Current | $ 14,771 | $ 13,554 |
Finance Lease, Liability, Current | 4,870 | 4,276 |
Operating Lease, Liability, Noncurrent | 39,282 | 32,588 |
Finance Lease, Liability, Noncurrent | $ 16,568 | $ 14,264 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 7 months 6 days | 4 years 3 months 3 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 4 months 24 days | 5 years 3 months 7 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.01% | 3.24% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.85% | 3.15% |
Entergy Mississippi [Member] | ||
Operating Lease, Liability, Current | $ 6,754 | $ 6,540 |
Finance Lease, Liability, Current | 3,059 | 1,974 |
Operating Lease, Liability, Noncurrent | 18,722 | 17,098 |
Finance Lease, Liability, Noncurrent | $ 19,602 | $ 6,604 |
Operating Lease, Weighted Average Remaining Lease Term | 5 years 4 months 2 days | 5 years 3 months 21 days |
Finance Lease, Weighted Average Remaining Lease Term | 17 years 9 months 25 days | 5 years 1 month 24 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.08% | 3.52% |
Finance Lease, Weighted Average Discount Rate, Percent | 5.08% | 2.87% |
Entergy New Orleans [Member] | ||
Operating Lease, Liability, Current | $ 1,681 | $ 1,650 |
Finance Lease, Liability, Current | 991 | 918 |
Operating Lease, Liability, Noncurrent | 4,377 | 4,217 |
Finance Lease, Liability, Noncurrent | $ 3,788 | $ 3,424 |
Operating Lease, Weighted Average Remaining Lease Term | 6 years 4 months 17 days | 6 years 29 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 8 months 23 days | 5 years 8 months 19 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.02% | 3.50% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.69% | 3.04% |
Entergy Texas [Member] | ||
Operating Lease, Liability, Current | $ 6,023 | $ 5,640 |
Finance Lease, Liability, Current | 1,865 | 1,654 |
Operating Lease, Liability, Noncurrent | 15,304 | 11,441 |
Finance Lease, Liability, Noncurrent | $ 6,849 | $ 6,440 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 5 months 8 days | 3 years 10 months 2 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 5 months 26 days | 5 years 8 months 1 day |
Operating Lease, Weighted Average Discount Rate, Percent | 4.43% | 3.63% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.76% | 3.07% |
Entergy Arkansas [Member] | ||
Operating Lease, Liability, Current | $ 15,514 | $ 14,140 |
Finance Lease, Liability, Current | 3,743 | 2,985 |
Operating Lease, Liability, Noncurrent | 46,211 | 41,874 |
Finance Lease, Liability, Noncurrent | $ 13,879 | $ 10,508 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 7 months 13 days | 4 years 6 months 18 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 6 months 25 days | 5 years 3 months 25 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.04% | 3.43% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.77% | 2.93% |
Leases Lease, Terms and Discoun
Leases Lease, Terms and Discount Rate (Details) | Dec. 31, 2023 | Dec. 31, 2022 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 5 months 15 days | 4 years 3 months 25 days |
Finance Lease, Weighted Average Remaining Lease Term | 8 years 7 months 9 days | 5 years 7 months 17 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.10% | 3.61% |
Finance Lease, Weighted Average Discount Rate, Percent | 4.64% | 3.95% |
Entergy Louisiana [Member] | ||
Operating Lease, Weighted Average Remaining Lease Term | 4 years 7 months 6 days | 4 years 3 months 3 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 4 months 24 days | 5 years 3 months 7 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.01% | 3.24% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.85% | 3.15% |
Entergy Mississippi [Member] | ||
Operating Lease, Weighted Average Remaining Lease Term | 5 years 4 months 2 days | 5 years 3 months 21 days |
Finance Lease, Weighted Average Remaining Lease Term | 17 years 9 months 25 days | 5 years 1 month 24 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.08% | 3.52% |
Finance Lease, Weighted Average Discount Rate, Percent | 5.08% | 2.87% |
Entergy New Orleans [Member] | ||
Operating Lease, Weighted Average Remaining Lease Term | 6 years 4 months 17 days | 6 years 29 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 8 months 23 days | 5 years 8 months 19 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.02% | 3.50% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.69% | 3.04% |
Entergy Texas [Member] | ||
Operating Lease, Weighted Average Remaining Lease Term | 4 years 5 months 8 days | 3 years 10 months 2 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 5 months 26 days | 5 years 8 months 1 day |
Operating Lease, Weighted Average Discount Rate, Percent | 4.43% | 3.63% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.76% | 3.07% |
Entergy Arkansas [Member] | ||
Operating Lease, Weighted Average Remaining Lease Term | 4 years 7 months 13 days | 4 years 6 months 18 days |
Finance Lease, Weighted Average Remaining Lease Term | 5 years 6 months 25 days | 5 years 3 months 25 days |
Operating Lease, Weighted Average Discount Rate, Percent | 4.04% | 3.43% |
Finance Lease, Weighted Average Discount Rate, Percent | 3.77% | 2.93% |
Leases Lease, Maturity (Details
Leases Lease, Maturity (Details) $ in Thousands | 12 Months Ended |
Dec. 31, 2023 USD ($) | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | $ 53,183 |
Finance Lease, Liability, to be Paid, Year Two | 18,243 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 44,744 |
Finance Lease, Liability, to be Paid, Year Three | 16,392 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 32,552 |
Finance Lease, Liability, to be Paid, Year Four | 13,920 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 14,038 |
Finance Lease, Liability, to be Paid, Year Five | 11,342 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 14,105 |
Finance Lease, Liability, to be Paid, after Year Five | 33,409 |
Lessee, Operating Lease, Liability, to be Paid | 226,033 |
Finance Lease, Liability, to be Paid | 113,243 |
Operating Lease, Cost | 18,617 |
Finance Lease, Interest Payment on Liability | 24,357 |
Present Value Net Minimum Operating Lease Payments | 207,416 |
Present Value Net Minimum Financing Lease Payments | 88,886 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 67,411 |
Finance Lease, Liability, to be Paid, Year One | 19,937 |
Entergy Louisiana [Member] | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | 13,908 |
Finance Lease, Liability, to be Paid, Year Two | 5,037 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 11,374 |
Finance Lease, Liability, to be Paid, Year Three | 4,279 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 8,493 |
Finance Lease, Liability, to be Paid, Year Four | 3,389 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 4,595 |
Finance Lease, Liability, to be Paid, Year Five | 2,545 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 4,035 |
Finance Lease, Liability, to be Paid, after Year Five | 3,199 |
Lessee, Operating Lease, Liability, to be Paid | 58,944 |
Finance Lease, Liability, to be Paid | 24,141 |
Operating Lease, Cost | 4,891 |
Finance Lease, Interest Payment on Liability | 2,703 |
Present Value Net Minimum Operating Lease Payments | 54,053 |
Present Value Net Minimum Financing Lease Payments | 21,438 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 16,539 |
Finance Lease, Liability, to be Paid, Year One | 5,692 |
Entergy Mississippi [Member] | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | 6,846 |
Finance Lease, Liability, to be Paid, Year Two | 3,093 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 5,409 |
Finance Lease, Liability, to be Paid, Year Three | 2,775 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 4,105 |
Finance Lease, Liability, to be Paid, Year Four | 2,322 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 2,212 |
Finance Lease, Liability, to be Paid, Year Five | 1,908 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 2,421 |
Finance Lease, Liability, to be Paid, after Year Five | 23,562 |
Lessee, Operating Lease, Liability, to be Paid | 28,645 |
Finance Lease, Liability, to be Paid | 37,048 |
Operating Lease, Cost | 3,170 |
Finance Lease, Interest Payment on Liability | 14,387 |
Present Value Net Minimum Operating Lease Payments | 25,475 |
Present Value Net Minimum Financing Lease Payments | 22,661 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 7,652 |
Finance Lease, Liability, to be Paid, Year One | 3,388 |
Entergy New Orleans [Member] | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | 1,442 |
Finance Lease, Liability, to be Paid, Year Two | 1,016 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 1,080 |
Finance Lease, Liability, to be Paid, Year Three | 932 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 704 |
Finance Lease, Liability, to be Paid, Year Four | 796 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 476 |
Finance Lease, Liability, to be Paid, Year Five | 603 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 1,376 |
Finance Lease, Liability, to be Paid, after Year Five | 812 |
Lessee, Operating Lease, Liability, to be Paid | 6,945 |
Finance Lease, Liability, to be Paid | 5,307 |
Operating Lease, Cost | 887 |
Finance Lease, Interest Payment on Liability | 528 |
Present Value Net Minimum Operating Lease Payments | 6,058 |
Present Value Net Minimum Financing Lease Payments | 4,779 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 1,867 |
Finance Lease, Liability, to be Paid, Year One | 1,148 |
Entergy Texas [Member] | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | 5,892 |
Finance Lease, Liability, to be Paid, Year Two | 1,975 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 4,736 |
Finance Lease, Liability, to be Paid, Year Three | 1,739 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 2,834 |
Finance Lease, Liability, to be Paid, Year Four | 1,413 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 1,563 |
Finance Lease, Liability, to be Paid, Year Five | 1,145 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 1,672 |
Finance Lease, Liability, to be Paid, after Year Five | 1,222 |
Lessee, Operating Lease, Liability, to be Paid | 23,525 |
Finance Lease, Liability, to be Paid | 9,633 |
Operating Lease, Cost | 2,198 |
Finance Lease, Interest Payment on Liability | 919 |
Present Value Net Minimum Operating Lease Payments | 21,327 |
Present Value Net Minimum Financing Lease Payments | 8,714 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 6,828 |
Finance Lease, Liability, to be Paid, Year One | 2,139 |
Entergy Arkansas [Member] | |
Lessee, Operating Lease, Liability, to be Paid, Year Two | 15,716 |
Finance Lease, Liability, to be Paid, Year Two | 4,179 |
Lessee, Operating Lease, Liability, to be Paid, Year Three | 13,855 |
Finance Lease, Liability, to be Paid, Year Three | 3,747 |
Lessee, Operating Lease, Liability, to be Paid, Year Four | 10,587 |
Finance Lease, Liability, to be Paid, Year Four | 3,088 |
Lessee, Operating Lease, Liability, to be Paid, Year Five | 4,597 |
Finance Lease, Liability, to be Paid, Year Five | 2,245 |
Lessee, Operating Lease, Liability, to be Paid, after Year Five | 4,598 |
Finance Lease, Liability, to be Paid, after Year Five | 2,918 |
Lessee, Operating Lease, Liability, to be Paid | 66,752 |
Finance Lease, Liability, to be Paid | 20,777 |
Operating Lease, Cost | 5,027 |
Finance Lease, Interest Payment on Liability | 3,155 |
Present Value Net Minimum Operating Lease Payments | 61,725 |
Present Value Net Minimum Financing Lease Payments | 17,622 |
Lessee, Operating Lease, Liability, to be Paid, Year One | 17,399 |
Finance Lease, Liability, to be Paid, Year One | $ 4,600 |
Retirement, Other Postretirem_3
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Narrative (Details) - USD ($) $ in Thousands | 1 Months Ended | 12 Months Ended | ||
Jan. 31, 2021 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Defined Benefit Plan Disclosure [Line Items] | ||||
Liability, Defined Benefit Plan, Noncurrent | $ 648,413 | $ 1,213,555 | ||
Liability, Defined Benefit Plan, Current | $ 59,508 | $ 104,845 | ||
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate | 4.75% | 4.75% | ||
Defined Benefit Plan, Plan Assets, Payment for Settlement | $ (410,110) | $ (604,753) | ||
Regulatory Asset, Noncurrent | 5,669,404 | 6,036,397 | ||
Pension & postretirement benefits expense deferral [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Regulatory Asset, Noncurrent | 32,700 | 30,600 | ||
Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 77,900 | 140,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 43,800 | 30,900 | $ 28,600 | |
Defined Benefit Plan, Benefit Obligation | 88,600 | 152,400 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 3,900 | 8,700 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 29,700 | 56,800 | ||
Common Stock Issued, Employee Stock Trust | 35,000 | |||
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits | 27,900 | 12,200 | 10,900 | |
Defined Benefit Plan Benefit Obligation, Current | 13,800 | 62,400 | ||
Defined Benefit Plan Benefit Obligation, Non-Current | 74,800 | 90,000 | ||
Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 5,460,601 | 5,242,098 | 6,993,110 | |
Defined Benefit Plan, Benefit Obligation | 5,915,404 | 6,166,106 | 8,409,620 | |
Liability, Defined Benefit Plan, Noncurrent | 454,803 | 924,008 | ||
Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 5,460,601 | 5,242,098 | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 5,600,000 | 5,700,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 253,739 | 390,458 | 471,815 | |
Defined Contribution Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Contribution Plan, Cost | $ 65,100 | 62,100 | 62,300 | |
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay | 5% | 6% | ||
Defined Contribution Plan Discretionary Employer Matching Contribution Percent | 4% | |||
Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | $ 673,141 | 623,824 | 771,319 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (13,810) | (12,597) | (25,580) | |
Defined Benefit Plan, Benefit Obligation | 837,644 | 865,854 | 1,189,682 | |
Liability, Defined Benefit Plan, Noncurrent | 118,797 | 199,546 | ||
Liability, Defined Benefit Plan, Current | 45,706 | 42,484 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (150,977) | (178,823) | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (22,558) | (25,550) | (33,069) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 45,900 | |||
Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 270,000 | |||
Entergy Arkansas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Liability, Defined Benefit Plan, Noncurrent | 8,901 | 118,020 | ||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (68,700) | (96,000) | ||
Regulatory Asset, Noncurrent | 1,885,361 | 1,810,281 | ||
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,935 | 2,192 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 637 | 282 | 343 | |
Defined Benefit Plan, Benefit Obligation | 2,313 | 2,433 | ||
Liability, Defined Benefit Plan, Noncurrent | 2,037 | 2,199 | ||
Liability, Defined Benefit Plan, Current | 276 | 234 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 379 | |||
Entergy Arkansas [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 991,894 | 961,178 | 1,302,588 | |
Defined Benefit Plan, Benefit Obligation | 1,117,585 | 1,168,098 | 1,579,346 | |
Liability, Defined Benefit Plan, Noncurrent | 125,691 | 206,920 | ||
Entergy Arkansas [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,048,901 | 1,008,152 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 49,450 | 74,774 | 92,919 | |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 274,814 | 255,117 | 315,495 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (1,879) | (5,665) | (11,084) | |
Defined Benefit Plan, Benefit Obligation | 155,987 | 164,018 | 221,183 | |
Liability, Defined Benefit Plan, Current | 0 | 0 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 2,096 | 1,885 | (1,121) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 529 | |||
Entergy Arkansas [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 55,112 | |||
Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Liability, Defined Benefit Plan, Noncurrent | 271,928 | 389,631 | ||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (103,100) | (146,600) | ||
Regulatory Asset, Noncurrent | 1,648,852 | 2,056,179 | ||
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 2,494 | 1,197 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 99 | 102 | 307 | |
Defined Benefit Plan, Benefit Obligation | 2,574 | 1,197 | ||
Liability, Defined Benefit Plan, Noncurrent | 2,266 | 1,013 | ||
Liability, Defined Benefit Plan, Current | 308 | 184 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 67 | 5 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 1 | 155 | ||
Entergy Louisiana [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 1,058,711 | 1,035,574 | 1,446,658 | |
Defined Benefit Plan, Benefit Obligation | 1,173,283 | 1,256,422 | 1,736,396 | |
Liability, Defined Benefit Plan, Noncurrent | 114,572 | 220,848 | ||
Entergy Louisiana [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,085,318 | 1,146,561 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 69,539 | 100,633 | 117,150 | |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 0 | 0 | 0 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 1,449 | 6,029 | 5,410 | |
Defined Benefit Plan, Benefit Obligation | 170,139 | 183,126 | 253,031 | |
Liability, Defined Benefit Plan, Noncurrent | 155,090 | 167,770 | ||
Liability, Defined Benefit Plan, Current | 15,049 | 15,356 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (88,354) | (94,323) | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (3,804) | (4,630) | (4,920) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 15,049 | |||
Entergy Louisiana [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 48,401 | |||
Entergy Mississippi [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Liability, Defined Benefit Plan, Noncurrent | 0 | 23,742 | ||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (31,400) | (48,000) | ||
Regulatory Asset, Noncurrent | 579,076 | 519,460 | ||
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,187 | 3,594 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 808 | 321 | 365 | |
Defined Benefit Plan, Benefit Obligation | 3,369 | 3,830 | ||
Liability, Defined Benefit Plan, Noncurrent | 2,895 | 3,616 | ||
Liability, Defined Benefit Plan, Current | 474 | 214 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 453 | 2 | ||
Entergy Mississippi [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 280,260 | 265,736 | 356,424 | |
Defined Benefit Plan, Benefit Obligation | 295,942 | 320,994 | 448,858 | |
Liability, Defined Benefit Plan, Noncurrent | 15,682 | 55,258 | ||
Entergy Mississippi [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 273,338 | 292,596 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 19,715 | 29,234 | 33,826 | |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 85,662 | 79,496 | 97,888 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (2,538) | (4,370) | (4,677) | |
Defined Benefit Plan, Benefit Obligation | 41,344 | 44,365 | 61,001 | |
Liability, Defined Benefit Plan, Current | 0 | 0 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (955) | (1,772) | (1,775) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 178 | |||
Entergy Mississippi [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 14,980 | |||
Entergy New Orleans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (5,300) | (16,200) | ||
Regulatory Asset, Noncurrent | 182,367 | 202,112 | ||
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 814 | 719 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 132 | 114 | 30 | |
Defined Benefit Plan, Benefit Obligation | 1,034 | 1,024 | ||
Liability, Defined Benefit Plan, Noncurrent | 928 | 992 | ||
Liability, Defined Benefit Plan, Current | 106 | 32 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Entergy New Orleans [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 117,923 | 119,710 | 172,366 | |
Defined Benefit Plan, Benefit Obligation | 133,950 | 140,436 | 195,380 | |
Liability, Defined Benefit Plan, Noncurrent | 16,027 | 20,726 | ||
Entergy New Orleans [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 125,878 | 128,499 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 3,678 | 9,779 | 9,859 | |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 100,536 | 91,140 | 111,137 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (4,318) | (6,720) | (6,420) | |
Defined Benefit Plan, Benefit Obligation | 21,685 | 23,971 | 31,866 | |
Liability, Defined Benefit Plan, Current | 0 | 0 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (916) | (916) | (916) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 205 | |||
Entergy New Orleans [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 4,931 | |||
Entergy Texas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (29,400) | (48,900) | ||
Regulatory Asset, Noncurrent | 596,606 | 578,682 | ||
Entergy Texas [Member] | Pension & postretirement benefits expense deferral [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Regulatory Asset, Noncurrent | 32,700 | 30,600 | ||
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,701 | 3,776 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 253 | 1,320 | 615 | |
Defined Benefit Plan, Benefit Obligation | 3,762 | 3,850 | ||
Liability, Defined Benefit Plan, Noncurrent | 3,314 | 3,402 | ||
Liability, Defined Benefit Plan, Current | 448 | 448 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 1,000 | 172 | ||
Entergy Texas [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 222,496 | 226,417 | 341,915 | |
Defined Benefit Plan, Benefit Obligation | 239,984 | 265,565 | 371,802 | |
Liability, Defined Benefit Plan, Noncurrent | 17,488 | 39,148 | ||
Entergy Texas [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 225,379 | 245,428 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 15,718 | 29,835 | 18,617 | |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 161,318 | 148,799 | 182,285 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (8,827) | (11,078) | (10,883) | |
Defined Benefit Plan, Benefit Obligation | 51,617 | 53,482 | 71,961 | |
Liability, Defined Benefit Plan, Current | 0 | 0 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (4,371) | (4,371) | (3,742) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 156 | |||
Entergy Texas [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 8,272 | |||
System Energy [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Liability, Defined Benefit Plan, Noncurrent | 19,491 | 40,750 | ||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (16,700) | (23,500) | ||
Regulatory Asset, Noncurrent | 446,360 | 415,121 | ||
System Energy [Member] | Qualified Pension Obligations [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 255,443 | 240,392 | 312,060 | |
Defined Benefit Plan, Benefit Obligation | 286,558 | 288,302 | 394,794 | |
Liability, Defined Benefit Plan, Noncurrent | 31,115 | 47,910 | ||
System Energy [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Accumulated Benefit Obligation | 267,432 | 269,583 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 12,627 | 21,702 | 29,348 | |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Amount | 45,402 | 42,434 | 54,650 | |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | (348) | (1,005) | (1,313) | |
Defined Benefit Plan, Benefit Obligation | 33,778 | 35,274 | 47,875 | |
Liability, Defined Benefit Plan, Current | 0 | 0 | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | ||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (293) | $ (319) | $ (436) | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 34 | |||
System Energy [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | $ 16,650 | |||
Minimum [Member] | Defined Contribution Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Contribution Plan, Employer Matching Contribution, Percent of Match | 70% | |||
Maximum [Member] | Defined Contribution Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Contribution Plan, Employer Matching Contribution, Percent of Match | 100% | 100% | ||
Domestic Equity Securities [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 32% | |||
Domestic Equity Securities [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 25% | |||
Domestic Equity Securities [Member] | Minimum [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 26% | |||
Domestic Equity Securities [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 20% | |||
Domestic Equity Securities [Member] | Maximum [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 38% | |||
Domestic Equity Securities [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 30% | |||
International Equity Securities [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 17% | |||
International Equity Securities [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 17% | |||
International Equity Securities [Member] | Minimum [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 14% | |||
International Equity Securities [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 12% | |||
International Equity Securities [Member] | Maximum [Member] | Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 20% | |||
International Equity Securities [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 22% | |||
Fixed Income Funds [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 58% | |||
Fixed Income Funds [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 53% | |||
Fixed Income Funds [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 63% | |||
Defined Benefit Plan Total Plan Assets [Member] | Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage | 10% | |||
Defined Benefit Plan Total Plan Assets [Member] | Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage | 10% |
Retirement, Other Postretirem_4
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Net Periodic Pension Cost (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | $ 14,654 | $ 24,734 | $ 26,578 |
Defined Benefit Plan, Interest Cost | 42,272 | 27,306 | 21,278 |
Expected return on assets | (36,732) | (43,420) | (43,220) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (22,558) | (25,550) | (33,069) |
Recognized net loss | (11,446) | 4,333 | 2,853 |
Net pension cost | (13,810) | (12,597) | (25,580) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | (4,434) | (858) | (3,168) |
Net (gain)/loss | (44,441) | (131,524) | 6,210 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 22,558 | 25,550 | 33,069 |
Amortization of net loss | (11,446) | 4,333 | 2,853 |
Total | (14,871) | (111,165) | 33,258 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (28,681) | (123,762) | 7,678 |
Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 77,900 | 140,000 | |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 29,700 | 56,800 | |
Net pension cost | 43,800 | 30,900 | 28,600 |
Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 5,600,000 | 5,700,000 | |
Service cost - benefits earned during the period | 101,182 | 138,085 | 165,278 |
Defined Benefit Plan, Interest Cost | 298,281 | 235,805 | 191,107 |
Expected return on assets | (388,030) | (402,504) | (424,572) |
Recognized net loss | 81,919 | 188,683 | 334,124 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (160,387) | (230,389) | (205,878) |
Net pension cost | 253,739 | 390,458 | 471,815 |
Net (gain)/loss | (213,636) | 6,113 | (448,532) |
Amortization of net loss | (81,919) | (188,683) | (334,124) |
Total | (455,942) | (412,959) | (988,534) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (202,203) | (22,501) | (516,719) |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 2,965 | 4,457 | 4,135 |
Defined Benefit Plan, Interest Cost | 8,002 | 5,050 | 3,726 |
Expected return on assets | (15,113) | (17,930) | (18,020) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 2,096 | 1,885 | (1,121) |
Recognized net loss | 171 | 873 | 196 |
Net pension cost | (1,879) | (5,665) | (11,084) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 0 | (273) | 85 |
Net (gain)/loss | (23,033) | 12,894 | 9,956 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | (2,096) | (1,885) | 1,121 |
Amortization of net loss | 171 | 873 | 196 |
Total | (25,300) | 10,409 | 10,796 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (27,179) | 4,744 | (288) |
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,935 | 2,192 | |
Net pension cost | 637 | 282 | 343 |
Entergy Arkansas [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,048,901 | 1,008,152 | |
Service cost - benefits earned during the period | 18,461 | 25,210 | 28,632 |
Defined Benefit Plan, Interest Cost | 56,026 | 45,378 | 35,683 |
Expected return on assets | (70,574) | (75,820) | (78,368) |
Recognized net loss | 19,400 | 43,597 | 69,290 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (26,137) | (36,409) | (37,682) |
Net pension cost | 49,450 | 74,774 | 92,919 |
Net (gain)/loss | (30,674) | 28,365 | (96,066) |
Amortization of net loss | (19,400) | (43,597) | (69,290) |
Total | (76,211) | (51,641) | (203,038) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (26,761) | 23,133 | (110,119) |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 3,379 | 5,633 | 6,174 |
Defined Benefit Plan, Interest Cost | 8,931 | 5,770 | 4,520 |
Expected return on assets | 0 | 0 | 0 |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (3,804) | (4,630) | (4,920) |
Recognized net loss | (7,057) | (744) | (364) |
Net pension cost | 1,449 | 6,029 | 5,410 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 4,434 | (323) | (357) |
Net (gain)/loss | (458) | (65,501) | (2,367) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 3,804 | 4,630 | 4,920 |
Amortization of net loss | (7,057) | (744) | (364) |
Total | 5,969 | (59,804) | 3,274 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | 7,418 | (53,775) | 8,684 |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 2,494 | 1,197 | |
Net pension cost | 99 | 102 | 307 |
Entergy Louisiana [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,085,318 | 1,146,561 | |
Service cost - benefits earned during the period | 24,716 | 33,520 | 38,271 |
Defined Benefit Plan, Interest Cost | 60,346 | 49,330 | 39,740 |
Expected return on assets | (75,757) | (82,478) | (89,821) |
Recognized net loss | 19,797 | 41,711 | 67,015 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (40,437) | (58,550) | (61,945) |
Net pension cost | 69,539 | 100,633 | 117,150 |
Net (gain)/loss | (71,016) | (15,604) | (89,534) |
Amortization of net loss | (19,797) | (41,711) | (67,015) |
Total | (131,250) | (115,865) | (218,494) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (61,711) | (15,232) | (101,344) |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 878 | 1,354 | 1,448 |
Defined Benefit Plan, Interest Cost | 2,170 | 1,401 | 1,110 |
Expected return on assets | (4,716) | (5,575) | (5,536) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (955) | (1,772) | (1,775) |
Recognized net loss | 85 | 222 | 76 |
Net pension cost | (2,538) | (4,370) | (4,677) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 0 | 1,300 | 0 |
Net (gain)/loss | (6,883) | 6,629 | (2,823) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 955 | 1,772 | 1,775 |
Amortization of net loss | 85 | 222 | 76 |
Total | (6,013) | 6,879 | (1,124) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (8,551) | 2,509 | (5,801) |
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,187 | 3,594 | |
Net pension cost | 808 | 321 | 365 |
Entergy Mississippi [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 273,338 | 292,596 | |
Service cost - benefits earned during the period | 5,775 | 8,043 | 9,070 |
Defined Benefit Plan, Interest Cost | 15,402 | 12,979 | 10,446 |
Expected return on assets | (19,423) | (20,168) | (22,407) |
Recognized net loss | 5,719 | 12,594 | 20,007 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (12,242) | (15,786) | (16,710) |
Net pension cost | 19,715 | 29,234 | 33,826 |
Net (gain)/loss | (20,220) | (4,743) | (29,675) |
Amortization of net loss | (5,719) | (12,594) | (20,007) |
Total | (38,181) | (33,123) | (66,392) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (18,466) | (3,889) | (32,566) |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 235 | 397 | 437 |
Defined Benefit Plan, Interest Cost | 1,160 | 694 | 521 |
Expected return on assets | (5,263) | (5,997) | (5,750) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (916) | (916) | (916) |
Recognized net loss | 466 | (898) | (712) |
Net pension cost | (4,318) | (6,720) | (6,420) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 0 | 0 | 0 |
Net (gain)/loss | (7,606) | 17,334 | (3,330) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 916 | 916 | 916 |
Amortization of net loss | 466 | (898) | (712) |
Total | (7,156) | 19,148 | (1,702) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (11,474) | 12,428 | (8,122) |
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 814 | 719 | |
Net pension cost | 132 | 114 | 30 |
Entergy New Orleans [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 125,878 | 128,499 | |
Service cost - benefits earned during the period | 1,955 | 2,745 | 3,038 |
Defined Benefit Plan, Interest Cost | 6,747 | 5,491 | 4,392 |
Expected return on assets | (8,798) | (9,920) | (10,598) |
Recognized net loss | 1,694 | 4,787 | 7,596 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (2,080) | (6,676) | (5,431) |
Net pension cost | 3,678 | 9,779 | 9,859 |
Net (gain)/loss | (3,183) | 525 | (16,159) |
Amortization of net loss | (1,694) | (4,787) | (7,596) |
Total | (6,957) | (10,938) | (29,186) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (3,279) | (1,159) | (19,327) |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 809 | 1,322 | 1,384 |
Defined Benefit Plan, Interest Cost | 2,597 | 1,596 | 1,269 |
Expected return on assets | (8,776) | (10,273) | (10,192) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (4,371) | (4,371) | (3,742) |
Recognized net loss | 914 | 648 | 398 |
Net pension cost | (8,827) | (11,078) | (10,883) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 0 | 0 | 3,776 |
Net (gain)/loss | (8,790) | 22,323 | 939 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 4,371 | 4,371 | 3,742 |
Amortization of net loss | 914 | 648 | 398 |
Total | (5,333) | 26,046 | 507 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (14,160) | 14,968 | (10,376) |
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,701 | 3,776 | |
Net pension cost | 253 | 1,320 | 615 |
Entergy Texas [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 225,379 | 245,428 | |
Service cost - benefits earned during the period | 4,328 | 5,999 | 6,921 |
Defined Benefit Plan, Interest Cost | 12,726 | 10,729 | 8,381 |
Expected return on assets | (16,641) | (18,317) | (21,158) |
Recognized net loss | 4,075 | 9,013 | 12,676 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (11,230) | (22,411) | (11,797) |
Net pension cost | 15,718 | 29,835 | 18,617 |
Net (gain)/loss | (16,759) | 13,363 | (18,217) |
Amortization of net loss | (4,075) | (9,013) | (12,676) |
Total | (32,064) | (18,061) | (42,690) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (16,346) | 11,774 | (24,073) |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Service cost - benefits earned during the period | 754 | 1,239 | 1,340 |
Defined Benefit Plan, Interest Cost | 1,726 | 1,116 | 878 |
Expected return on assets | (2,535) | (3,162) | (3,156) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (293) | (319) | (436) |
Recognized net loss | 0 | 121 | 61 |
Net pension cost | (348) | (1,005) | (1,313) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax | 0 | (141) | (69) |
Net (gain)/loss | (3,942) | 1,208 | 210 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax | 293 | 319 | 436 |
Amortization of net loss | 0 | 121 | 61 |
Total | (3,649) | 1,547 | 654 |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | (3,997) | 542 | (659) |
System Energy [Member] | Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Accumulated Benefit Obligation | 267,432 | 269,583 | |
Service cost - benefits earned during the period | 5,749 | 7,746 | 8,851 |
Defined Benefit Plan, Interest Cost | 13,852 | 11,286 | 9,087 |
Expected return on assets | (17,585) | (18,173) | (19,254) |
Recognized net loss | 4,236 | 10,938 | 18,404 |
Defined Benefit Plan, Benefit Obligation, Payment for Settlement | (6,375) | (9,905) | (12,260) |
Net pension cost | 12,627 | 21,702 | 29,348 |
Net (gain)/loss | (3,268) | (7,063) | (27,617) |
Amortization of net loss | (4,236) | (10,938) | (18,404) |
Total | (13,879) | (27,906) | (58,281) |
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax | $ (1,252) | $ (6,204) | $ (28,933) |
Retirement, Other Postretirem_5
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | $ (59,508) | $ (104,845) | |
Liability, Defined Benefit Plan, Noncurrent | (648,413) | (1,213,555) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (410,110) | (604,753) | |
Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 865,854 | 1,189,682 | |
Defined Benefit Plan, Service Cost | 14,654 | 24,734 | $ 26,578 |
Defined Benefit Plan, Interest Cost | 42,272 | 27,306 | 21,278 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | (858) | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (4,303) | (297,128) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 18,669 | 22,486 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (95,348) | (100,632) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 280 | 264 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 837,644 | 865,854 | 1,189,682 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 623,824 | 771,319 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 76,870 | (122,184) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 49,126 | 52,835 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 18,669 | 22,486 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (95,348) | (100,632) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 673,141 | 623,824 | 771,319 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (164,503) | (242,030) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | (45,706) | (42,484) | |
Liability, Defined Benefit Plan, Noncurrent | (118,797) | (199,546) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | (21,465) | (29,323) | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | 33,617 | (16,956) | |
Defined Benefit Plan Regulatory Liability Before Tax | (55,082) | (12,367) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | (34,899) | (45,167) | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | (116,078) | (133,656) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (150,977) | (178,823) | |
Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 6,166,106 | 8,409,620 | |
Defined Benefit Plan, Service Cost | 101,182 | 138,085 | |
Defined Benefit Plan, Interest Cost | 298,281 | 235,805 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 123,237 | (1,660,463) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (773,402) | (956,941) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 5,915,404 | 6,166,106 | 8,409,620 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 5,242,098 | 6,993,110 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 724,903 | (1,264,071) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 267,002 | 470,000 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (773,402) | (956,941) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 5,460,601 | 5,242,098 | 6,993,110 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (454,803) | (924,008) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (454,803) | (924,008) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (1,447,978) | (1,842,348) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 347,268 | 408,839 | |
Entergy Arkansas [Member] | |||
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (8,901) | (118,020) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (68,700) | (96,000) | |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 164,018 | 221,183 | |
Defined Benefit Plan, Service Cost | 2,965 | 4,457 | 4,135 |
Defined Benefit Plan, Interest Cost | 8,002 | 5,050 | 3,726 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 273 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (6,403) | (54,923) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 3,131 | 5,521 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (15,759) | (17,585) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 33 | 42 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 155,987 | 164,018 | 221,183 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 255,117 | 315,495 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 31,743 | (49,887) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 582 | 1,573 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 3,131 | 5,521 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (15,759) | (17,585) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 274,814 | 255,117 | 315,495 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | 118,827 | 91,099 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | 0 | 0 | |
Assets for Plan Benefits, Defined Benefit Plan | 118,827 | 91,099 | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | 4,983 | 7,079 | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | 17,980 | (5,224) | |
Defined Benefit Plan Regulatory Liability Before Tax | (12,997) | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | |
Entergy Arkansas [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 1,168,098 | 1,579,346 | |
Defined Benefit Plan, Service Cost | 18,461 | 25,210 | |
Defined Benefit Plan, Interest Cost | 56,026 | 45,378 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 39,643 | (280,691) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (164,643) | (201,145) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 1,117,585 | 1,168,098 | 1,579,346 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 961,178 | 1,302,588 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 140,891 | (233,236) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 54,468 | 92,971 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (164,643) | (201,145) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 991,894 | 961,178 | 1,302,588 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (125,691) | (206,920) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (125,691) | (206,920) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (485,113) | (561,323) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Entergy Louisiana [Member] | |||
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (271,928) | (389,631) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (103,100) | (146,600) | |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 183,126 | 253,031 | |
Defined Benefit Plan, Service Cost | 3,379 | 5,633 | 6,174 |
Defined Benefit Plan, Interest Cost | 8,931 | 5,770 | 4,520 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | 323 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (458) | (65,501) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 4,317 | 5,081 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (24,768) | (21,268) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 46 | 57 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 170,139 | 183,126 | 253,031 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 0 | 0 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 0 | 0 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 20,451 | 16,187 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 4,317 | 5,081 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (24,768) | (21,268) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 0 | 0 | 0 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (170,139) | (183,126) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | (15,049) | (15,356) | |
Liability, Defined Benefit Plan, Noncurrent | (155,090) | (167,770) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | 0 | 0 | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | (12,645) | (12,015) | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | (75,709) | (82,308) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (88,354) | (94,323) | |
Entergy Louisiana [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 1,256,422 | 1,736,396 | |
Defined Benefit Plan, Service Cost | 24,716 | 33,520 | |
Defined Benefit Plan, Interest Cost | 60,346 | 49,330 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 1,925 | (357,572) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (170,126) | (205,252) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 1,173,283 | 1,256,422 | 1,736,396 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 1,035,574 | 1,446,658 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 148,698 | (259,490) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 44,565 | 53,658 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (170,126) | (205,252) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 1,058,711 | 1,035,574 | 1,446,658 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (114,572) | (220,848) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (114,572) | (220,848) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (319,116) | (445,116) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 13,296 | 18,546 | |
Entergy Mississippi [Member] | |||
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | 0 | (23,742) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (31,400) | (48,000) | |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 44,365 | 61,001 | |
Defined Benefit Plan, Service Cost | 878 | 1,354 | 1,448 |
Defined Benefit Plan, Interest Cost | 2,170 | 1,401 | 1,110 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | (1,300) | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (1,650) | (14,465) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 1,386 | 1,443 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (5,815) | (5,075) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 10 | 6 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 41,344 | 44,365 | 61,001 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 79,496 | 97,888 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 9,949 | (15,519) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 646 | 759 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 1,386 | 1,443 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (5,815) | (5,075) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 85,662 | 79,496 | 97,888 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | 44,318 | 35,131 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | 0 | 0 | |
Assets for Plan Benefits, Defined Benefit Plan | 44,318 | 35,131 | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | (2,682) | (3,637) | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | 4,815 | (2,153) | |
Defined Benefit Plan Regulatory Liability Before Tax | (7,497) | (1,484) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | |
Entergy Mississippi [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 320,994 | 448,858 | |
Defined Benefit Plan, Service Cost | 5,775 | 8,043 | |
Defined Benefit Plan, Interest Cost | 15,402 | 12,979 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (328) | (88,303) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (45,901) | (60,583) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 295,942 | 320,994 | 448,858 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 265,736 | 356,424 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 39,315 | (63,392) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 21,110 | 33,287 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (45,901) | (60,583) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 280,260 | 265,736 | 356,424 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (15,682) | (55,258) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (15,682) | (55,258) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (102,208) | (140,389) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Entergy New Orleans [Member] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (5,300) | (16,200) | |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 23,971 | 31,866 | |
Defined Benefit Plan, Service Cost | 235 | 397 | 437 |
Defined Benefit Plan, Interest Cost | 1,160 | 694 | 521 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (1,676) | (6,867) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 374 | 440 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (2,384) | (2,566) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 5 | 7 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 21,685 | 23,971 | 31,866 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 91,140 | 111,137 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 11,193 | (18,204) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 213 | 333 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 374 | 440 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (2,384) | (2,566) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 100,536 | 91,140 | 111,137 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | 78,851 | 67,169 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | 0 | 0 | |
Assets for Plan Benefits, Defined Benefit Plan | 78,851 | 67,169 | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | (1,982) | (2,898) | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | 5,843 | (2,229) | |
Defined Benefit Plan Regulatory Liability Before Tax | (7,825) | (669) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | |
Entergy New Orleans [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 140,436 | 195,380 | |
Defined Benefit Plan, Service Cost | 1,955 | 2,745 | |
Defined Benefit Plan, Interest Cost | 6,747 | 5,491 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 4,590 | (40,462) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (19,778) | (22,718) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 133,950 | 140,436 | 195,380 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 119,710 | 172,366 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 16,571 | (31,067) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 1,420 | 1,129 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (19,778) | (22,718) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 117,923 | 119,710 | 172,366 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (16,027) | (20,726) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (16,027) | (20,726) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (44,911) | (51,868) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Entergy Texas [Member] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (29,400) | (48,900) | |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 53,482 | 71,961 | |
Defined Benefit Plan, Service Cost | 809 | 1,322 | 1,384 |
Defined Benefit Plan, Interest Cost | 2,597 | 1,596 | 1,269 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 337 | (16,291) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 680 | 924 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (6,299) | (6,046) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 11 | 16 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 51,617 | 53,482 | 71,961 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 148,799 | 182,285 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 17,903 | (28,341) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 235 | ||
Defined Benefit Plan Refund to Employer | (23) | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 680 | 924 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (6,299) | (6,046) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 161,318 | 148,799 | 182,285 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | 109,701 | 95,317 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | 0 | 0 | |
Assets for Plan Benefits, Defined Benefit Plan | 109,701 | 95,317 | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | (11,790) | (16,161) | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (14,542) | (24,246) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | |
Entergy Texas [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 265,565 | 371,802 | |
Defined Benefit Plan, Service Cost | 4,328 | 5,999 | |
Defined Benefit Plan, Interest Cost | 12,726 | 10,729 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (1,416) | (65,795) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (41,219) | (57,170) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 239,984 | 265,565 | 371,802 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 226,417 | 341,915 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 31,984 | (60,841) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 5,314 | 2,513 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (41,219) | (57,170) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 222,496 | 226,417 | 341,915 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (17,488) | (39,148) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (17,488) | (39,148) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (63,665) | (95,729) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
System Energy [Member] | |||
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (19,491) | (40,750) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Plan Assets, Payment for Settlement | (16,700) | (23,500) | |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 35,274 | 47,875 | |
Defined Benefit Plan, Service Cost | 754 | 1,239 | 1,340 |
Defined Benefit Plan, Interest Cost | 1,726 | 1,116 | 878 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 141 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | (1,075) | (10,679) | |
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 994 | 1,222 | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (3,908) | (5,657) | |
Defined Benefit Plan, Benefit Obligation, Prescription Drug Subsidy Receipt | 13 | 17 | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 33,778 | 35,274 | 47,875 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 42,434 | 54,650 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 5,402 | (8,725) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 480 | 944 | |
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 994 | 1,222 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (3,908) | (5,657) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 45,402 | 42,434 | 54,650 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | 11,624 | 7,160 | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Current | 0 | 0 | |
Assets for Plan Benefits, Defined Benefit Plan | 11,624 | 7,160 | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax | (496) | (789) | |
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (112) | (4,054) | |
Defined Benefit Plan Regulatory Liability Before Tax | (384) | ||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | 0 | 0 | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 | |
System Energy [Member] | Qualified Pension Obligations [Member] | |||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation, Beginning Balance | 288,302 | 394,794 | |
Defined Benefit Plan, Service Cost | 5,749 | 7,746 | |
Defined Benefit Plan, Interest Cost | 13,852 | 11,286 | |
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | 14,522 | (81,504) | |
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (35,867) | (44,020) | |
Defined Benefit Plan, Benefit Obligation, Ending Balance | 286,558 | 288,302 | 394,794 |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Plan Assets, Amount, Beginning Balance | 240,392 | 312,060 | |
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss) | 35,375 | (56,267) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 15,543 | 28,619 | |
Defined Benefit Plan, Plan Assets, Benefits Paid | (35,867) | (44,020) | |
Defined Benefit Plan, Plan Assets, Amount, Ending Balance | 255,443 | 240,392 | $ 312,060 |
Defined Benefit Plan, Funded (Unfunded) Status of Plan | (31,115) | (47,910) | |
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract] | |||
Liability, Defined Benefit Plan, Noncurrent | (31,115) | (47,910) | |
Amounts recognized as a regulatory asset (before tax) [Abstract] | |||
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax | (111,996) | (125,876) | |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax [Abstract] | |||
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax | $ 0 | $ 0 |
Retirement, Other Postretirem_6
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Projected Benefit Obligations (Details) - Non Qualified Pension Plans [Member] - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Defined Benefit Plan, Benefit Obligation | $ 88,600 | $ 152,400 |
Defined Benefit Plan, Accumulated Benefit Obligation | 77,900 | 140,000 |
Entergy Arkansas [Member] | ||
Defined Benefit Plan, Benefit Obligation | 2,313 | 2,433 |
Defined Benefit Plan, Accumulated Benefit Obligation | 1,935 | 2,192 |
Entergy Louisiana [Member] | ||
Defined Benefit Plan, Benefit Obligation | 2,574 | 1,197 |
Defined Benefit Plan, Accumulated Benefit Obligation | 2,494 | 1,197 |
Entergy Mississippi [Member] | ||
Defined Benefit Plan, Benefit Obligation | 3,369 | 3,830 |
Defined Benefit Plan, Accumulated Benefit Obligation | 3,187 | 3,594 |
Entergy New Orleans [Member] | ||
Defined Benefit Plan, Benefit Obligation | 1,034 | 1,024 |
Defined Benefit Plan, Accumulated Benefit Obligation | 814 | 719 |
Entergy Texas [Member] | ||
Defined Benefit Plan, Benefit Obligation | 3,762 | 3,850 |
Defined Benefit Plan, Accumulated Benefit Obligation | $ 3,701 | $ 3,776 |
Retirement, Other Postretirem_7
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Accumulated Benefit Obligations (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | $ 5,600,000 | $ 5,700,000 |
Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 77,900 | 140,000 |
Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | (858) |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 49,126 | 52,835 |
Defined Benefit Plan Regulatory Liability Before Tax | (55,082) | (12,367) |
Entergy Arkansas [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,048,901 | 1,008,152 |
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,935 | 2,192 |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 273 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 582 | 1,573 |
Defined Benefit Plan Regulatory Asset Before Tax | 12,303 | |
Defined Benefit Plan Regulatory Liability Before Tax | (12,997) | |
Entergy Louisiana [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,085,318 | 1,146,561 |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 2,494 | 1,197 |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | 323 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 20,451 | 16,187 |
Defined Benefit Plan Regulatory Asset Before Tax | 0 | 0 |
Entergy Mississippi [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 273,338 | 292,596 |
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,187 | 3,594 |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | (1,300) |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 646 | 759 |
Defined Benefit Plan Regulatory Liability Before Tax | (7,497) | (1,484) |
Entergy New Orleans [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 125,878 | 128,499 |
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 814 | 719 |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 213 | 333 |
Defined Benefit Plan Regulatory Liability Before Tax | (7,825) | (669) |
Entergy Texas [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 225,379 | 245,428 |
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,701 | 3,776 |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 235 | |
Defined Benefit Plan Regulatory Asset Before Tax | 2,752 | 8,085 |
System Energy [Member] | Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 267,432 | 269,583 |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 141 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 480 | 944 |
Defined Benefit Plan Regulatory Asset Before Tax | $ 3,265 | |
Defined Benefit Plan Regulatory Liability Before Tax | $ (384) |
Retirement, Other Postretirem_8
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Amounts Recorded On The Balance Sheet (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Liability, Defined Benefit Plan, Current | $ (59,508) | $ (104,845) |
Liability, Defined Benefit Plan, Noncurrent | (648,413) | (1,213,555) |
Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 77,900 | 140,000 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 3,900 | 8,700 |
Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 18,669 | 22,486 |
Liability, Defined Benefit Plan, Current | (45,706) | (42,484) |
Liability, Defined Benefit Plan, Noncurrent | (118,797) | (199,546) |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (150,977) | (178,823) |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | (858) |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 49,126 | 52,835 |
Defined Benefit Plan Regulatory Liability Before Tax | (55,082) | (12,367) |
Entergy Arkansas [Member] | ||
Liability, Defined Benefit Plan, Noncurrent | (8,901) | (118,020) |
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 1,935 | 2,192 |
Liability, Defined Benefit Plan, Current | (276) | (234) |
Liability, Defined Benefit Plan, Noncurrent | (2,037) | (2,199) |
Liability, Defined Benefit Plan | (2,313) | (2,433) |
Assets for Plan Benefits, Defined Benefit Plan | 857 | 512 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 3,131 | 5,521 |
Liability, Defined Benefit Plan, Current | 0 | 0 |
Assets for Plan Benefits, Defined Benefit Plan | 118,827 | 91,099 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Defined Benefit Plan Regulatory Asset Before Tax | 12,303 | |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 273 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 582 | 1,573 |
Defined Benefit Plan Regulatory Liability Before Tax | (12,997) | |
Entergy Louisiana [Member] | ||
Liability, Defined Benefit Plan, Noncurrent | (271,928) | (389,631) |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 2,494 | 1,197 |
Liability, Defined Benefit Plan, Current | (308) | (184) |
Liability, Defined Benefit Plan, Noncurrent | (2,266) | (1,013) |
Liability, Defined Benefit Plan | (2,574) | (1,197) |
Assets for Plan Benefits, Defined Benefit Plan | 1,604 | 119 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 67 | 5 |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 4,317 | 5,081 |
Liability, Defined Benefit Plan, Current | (15,049) | (15,356) |
Liability, Defined Benefit Plan, Noncurrent | (155,090) | (167,770) |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | (88,354) | (94,323) |
Defined Benefit Plan Regulatory Asset Before Tax | 0 | 0 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | (4,434) | 323 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 20,451 | 16,187 |
Entergy Mississippi [Member] | ||
Liability, Defined Benefit Plan, Noncurrent | 0 | (23,742) |
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,187 | 3,594 |
Liability, Defined Benefit Plan, Current | (474) | (214) |
Liability, Defined Benefit Plan, Noncurrent | (2,895) | (3,616) |
Liability, Defined Benefit Plan | (3,369) | (3,830) |
Assets for Plan Benefits, Defined Benefit Plan | 1,303 | 1,291 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 1,386 | 1,443 |
Liability, Defined Benefit Plan, Current | 0 | 0 |
Assets for Plan Benefits, Defined Benefit Plan | 44,318 | 35,131 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | (1,300) |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 646 | 759 |
Defined Benefit Plan Regulatory Liability Before Tax | (7,497) | (1,484) |
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 814 | 719 |
Liability, Defined Benefit Plan, Current | (106) | (32) |
Liability, Defined Benefit Plan, Noncurrent | (928) | (992) |
Liability, Defined Benefit Plan | (1,034) | (1,024) |
Assets for Plan Benefits, Defined Benefit Plan | 5 | 111 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 374 | 440 |
Liability, Defined Benefit Plan, Current | 0 | 0 |
Assets for Plan Benefits, Defined Benefit Plan | 78,851 | 67,169 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 213 | 333 |
Defined Benefit Plan Regulatory Liability Before Tax | (7,825) | (669) |
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan, Accumulated Benefit Obligation | 3,701 | 3,776 |
Liability, Defined Benefit Plan, Current | (448) | (448) |
Liability, Defined Benefit Plan, Noncurrent | (3,314) | (3,402) |
Liability, Defined Benefit Plan | (3,762) | (3,850) |
Liability, Defined Benefit Pension Plan | (2,526) | (2,615) |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 680 | 924 |
Liability, Defined Benefit Plan, Current | 0 | 0 |
Assets for Plan Benefits, Defined Benefit Plan | 109,701 | 95,317 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Defined Benefit Plan Regulatory Asset Before Tax | 2,752 | 8,085 |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 0 |
Defined Benefit Plan Refund to Employer | (23) | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 235 | |
System Energy [Member] | ||
Liability, Defined Benefit Plan, Noncurrent | (19,491) | (40,750) |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 994 | 1,222 |
Liability, Defined Benefit Plan, Current | 0 | 0 |
Assets for Plan Benefits, Defined Benefit Plan | 11,624 | 7,160 |
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, before Tax | 0 | 0 |
Defined Benefit Plan Regulatory Asset Before Tax | 3,265 | |
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment | 0 | 141 |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 480 | $ 944 |
Defined Benefit Plan Regulatory Liability Before Tax | $ (384) |
Retirement, Other Postretirem_9
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Reclassification Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | $ 13,586 | $ 15,337 |
Amortization of loss | 6,590 | (33,859) |
Settlement loss | (10,848) | (25,321) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 9,328 | (43,843) |
Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | (452) | (715) |
Amortization of loss | (593) | (1,331) |
Settlement loss | (3,004) | (1,685) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (4,049) | (3,731) |
Pension Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 0 | 0 |
Amortization of loss | (4,407) | (30,147) |
Settlement loss | (7,844) | (23,636) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (12,251) | (53,783) |
Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 14,038 | 16,052 |
Amortization of loss | 11,590 | (2,381) |
Settlement loss | 0 | 0 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 25,628 | 13,671 |
Entergy Louisiana [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 3,804 | 4,630 |
Amortization of loss | 6,263 | (927) |
Settlement loss | (1,617) | (2,342) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 8,450 | 1,361 |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 0 | 0 |
Amortization of loss | (2) | (2) |
Settlement loss | 0 | 0 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (2) | (2) |
Entergy Louisiana [Member] | Pension Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 0 | 0 |
Amortization of loss | (792) | (1,669) |
Settlement loss | (1,617) | (2,342) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (2,409) | (4,011) |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Amortization of prior service cost | 3,804 | 4,630 |
Amortization of loss | 7,057 | 744 |
Settlement loss | 0 | 0 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | $ 10,861 | $ 5,374 |
Retirement, Other Postretire_10
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Plan Assets, Asset Allocations Targets (Details) | Dec. 31, 2023 | Dec. 31, 2022 |
Qualified Pension Plans [Member] | Domestic Equity Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 32% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 33% | 42% |
Qualified Pension Plans [Member] | Domestic Equity Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 26% | |
Qualified Pension Plans [Member] | Domestic Equity Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 38% | |
Qualified Pension Plans [Member] | International Equity Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 17% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 18% | 22% |
Qualified Pension Plans [Member] | International Equity Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 14% | |
Qualified Pension Plans [Member] | International Equity Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 20% | |
Qualified Pension Plans [Member] | Other Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 0% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 0% | 3% |
Qualified Pension Plans [Member] | Other Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 0% | |
Qualified Pension Plans [Member] | Other Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 10% | |
Qualified Pension Plans [Member] | Intermediate Fixed Income Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 8% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 9% | 11% |
Qualified Pension Plans [Member] | Intermediate Fixed Income Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 7% | |
Qualified Pension Plans [Member] | Intermediate Fixed Income Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 9% | |
Qualified Pension Plans [Member] | Long Duration Fixed Income Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 43% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 40% | 22% |
Qualified Pension Plans [Member] | Long Duration Fixed Income Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 39% | |
Qualified Pension Plans [Member] | Long Duration Fixed Income Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 47% | |
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 25% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 28% | 25% |
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 20% | |
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 30% | |
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 17% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 17% | 18% |
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 12% | |
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 22% | |
Other Postretirement Benefits Plan [Member] | Fixed Income Funds [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 58% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 55% | 57% |
Other Postretirement Benefits Plan [Member] | Fixed Income Funds [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 53% | |
Other Postretirement Benefits Plan [Member] | Fixed Income Funds [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 63% | |
Other Postretirement Benefits Plan [Member] | Other Securities [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 0% | |
Defined Benefit Plan, Plan Assets, Actual Allocation, Percentage | 0% | 0% |
Other Postretirement Benefits Plan [Member] | Other Securities [Member] | Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 0% | |
Other Postretirement Benefits Plan [Member] | Other Securities [Member] | Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage | 5% |
Retirement, Other Postretire_11
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Investments Held For Qualified Pension And Other Postretirement Plans Measured At Fair Value (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 |
Qualified Pension Plans [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan Fair Value Of Plan Assets Cash | $ 1,488 | $ 10,601 | |
Defined Benefit Plan Fair Value Of Plan Assets Other Pending Transactions | (22,404) | (13,813) | |
Defined Benefit Plan Fair Value Of Plan Assets Other Postretirement Assets Included In Total Investments | (64,391) | (61,285) | |
Defined Benefit Plan, Plan Assets, Amount | 5,460,601 | 5,242,098 | |
Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 10,827 | 12,178 | |
Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 715,452 | 807,437 | |
Qualified Pension Plans [Member] | Defined Benefit Plan, Common Collective Trust [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 2,066,247 | 2,516,688 | |
Qualified Pension Plans [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 1,085,231 | 673,348 | |
Qualified Pension Plans [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 924,904 | 525,184 | |
Qualified Pension Plans [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 657,691 | 750,454 | |
Qualified Pension Plans [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 79,657 | 15,395 | |
Qualified Pension Plans [Member] | Other Contract [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 5,899 | 5,911 | |
Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 5,545,908 | 5,306,595 | |
Other Postretirement Benefits Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan Fair Value Of Plan Assets Other Pending Transactions | 2,868 | 486 | |
Defined Benefit Plan Fair Value Of Plan Assets Other Postretirement Assets Included In Qualified Pension Investments | 64,391 | 61,285 | |
Defined Benefit Plan, Plan Assets, Amount | 673,141 | 623,824 | $ 771,319 |
Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Common Collective Trust [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 276,560 | 241,676 | |
Other Postretirement Benefits Plan [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 164,740 | 147,939 | |
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 106,523 | 113,273 | |
Other Postretirement Benefits Plan [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 548 | 3,016 | |
Other Postretirement Benefits Plan [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 57,511 | 56,149 | |
Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 605,882 | 562,053 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 10,827 | 12,178 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 715,452 | 807,437 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 34,364 | 221,582 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 774 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Other Contract [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 761,417 | 1,041,197 | |
Fair Value, Inputs, Level 1 [Member] | Other Postretirement Benefits Plan [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 80,219 | 69,503 | |
Fair Value, Inputs, Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 548 | 3,016 | |
Fair Value, Inputs, Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 80,767 | 72,519 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 1,085,231 | 673,348 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 924,904 | 525,184 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 2,718 | 2,595 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 78,883 | 15,395 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Other Contract [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 5,899 | 5,911 | |
Fair Value, Inputs, Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 2,097,635 | 1,222,433 | |
Fair Value, Inputs, Level 2 [Member] | Other Postretirement Benefits Plan [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 84,521 | 78,436 | |
Fair Value, Inputs, Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 106,523 | 113,273 | |
Fair Value, Inputs, Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 57,511 | 56,149 | |
Fair Value, Inputs, Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 248,555 | 247,858 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Other Contract [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Other Postretirement Benefits Plan [Member] | US Treasury and Government [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount | $ 0 | $ 0 |
Retirement, Other Postretire_12
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Estimated Future Benefit Payments (Details) $ in Thousands | Dec. 31, 2023 USD ($) |
Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | $ 463,557 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 449,803 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 450,945 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 449,510 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 450,827 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 2,222,959 |
Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 13,802 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 10,894 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 8,507 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 14,374 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 9,325 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 36,584 |
Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 74,649 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 70,720 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 67,105 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 63,949 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 61,234 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 283,477 |
Entergy Arkansas [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 90,682 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 89,113 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 88,427 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 87,845 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 87,719 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 429,882 |
Entergy Arkansas [Member] | Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 276 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 474 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 160 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 149 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 288 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 938 |
Entergy Arkansas [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 13,697 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 12,913 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 12,342 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 11,767 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 11,424 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 54,789 |
Entergy Louisiana [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 95,706 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 92,420 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 92,499 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 91,485 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 91,450 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 444,131 |
Entergy Louisiana [Member] | Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 308 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 301 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 288 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 265 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 270 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 941 |
Entergy Louisiana [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 15,049 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 14,380 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 13,676 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 13,037 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 12,348 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 57,264 |
Entergy Mississippi [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 25,534 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 24,816 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 25,210 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 24,686 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 24,147 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 115,629 |
Entergy Mississippi [Member] | Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 474 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 547 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 461 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 642 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 395 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 1,326 |
Entergy Mississippi [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 3,521 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 3,386 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 3,256 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 3,126 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 3,121 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 14,563 |
Entergy New Orleans [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 11,300 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 10,799 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 10,910 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 10,566 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 10,458 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 48,870 |
Entergy New Orleans [Member] | Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 106 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 143 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 139 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 224 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 141 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 529 |
Entergy New Orleans [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 2,200 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 2,086 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 1,942 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 1,785 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 1,640 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 7,297 |
Entergy Texas [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 21,807 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 21,019 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 21,268 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 20,407 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 20,074 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 92,182 |
Entergy Texas [Member] | Non Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 448 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 423 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 445 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 395 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 369 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 1,524 |
Entergy Texas [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 5,187 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 4,874 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 4,436 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 4,215 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 3,937 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 17,857 |
System Energy [Member] | Qualified Pension Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 24,163 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 22,053 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 21,612 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 22,665 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 22,107 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | 109,712 |
System Energy [Member] | Other Postretirement Benefit Obligations [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Plan, Expected Future Benefit Payment, Year One | 2,811 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Two | 2,668 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Three | 2,434 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Four | 2,320 |
Defined Benefit Plan, Expected Future Benefit Payment, Year Five | 2,266 |
Defined Benefit Plan, Expected Future Benefit Payment, after Year Five for Next Five Years | $ 11,270 |
Retirement, Other Postretire_13
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Expected Employer Contributions (Details) $ in Thousands | Dec. 31, 2023 USD ($) |
Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | $ 270,000 |
Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 45,900 |
Entergy Arkansas [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 55,112 |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 529 |
Entergy Louisiana [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 48,401 |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 15,049 |
Entergy Mississippi [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 14,980 |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 178 |
Entergy New Orleans [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 4,931 |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 205 |
Entergy Texas [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 8,272 |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 156 |
System Energy [Member] | Pension Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | 16,650 |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | $ 34 |
Retirement, Other Postretire_14
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Actuarial Assumptions Used In Determining Pension And Other Postretirement Benefit Obligation (Details) | 12 Months Ended | |
Dec. 31, 2023 | Dec. 31, 2022 | |
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate | 4% | 4% |
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate | 4.75% | 4.75% |
Pre Sixty Five Retirees [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Health Care Cost Trend Rate Assumed, Next Fiscal Year | 6.95% | 6.65% |
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate | 2032 | 2032 |
Post Sixty Five Retirees [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Health Care Cost Trend Rate Assumed, Next Fiscal Year | 7.88% | 7.50% |
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate | 2032 | 2032 |
Other Postretirement Benefits Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 5.01% | 5.20% |
Pension Plan [Member] | Nonqualified Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.68% | 4.98% |
Pension Plan [Member] | Qualified Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate, Blended | 0.00051% | 5.24% |
Minimum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase | 0.0004% | 0.0004% |
Minimum [Member] | Pension Plan [Member] | Qualified Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 0.0005% | 5.21% |
Maximum [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase | 0.00044% | 0.00044% |
Maximum [Member] | Pension Plan [Member] | Qualified Plan [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 0.00051% | 5.27% |
Retirement, Other Postretire_15
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Actuarial Assumptions Used In Determining Net Periodic And Other Postretirement Benefit Obligation (Details) | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate Net Periodic Pension and Other Postretirement Benefit Costs | 4.75% | 4.75% | 4.75% |
Pre Sixty Five Retirees [Member] | |||
Defined Benefit Plan, Health Care Cost Trend Rate, Net Periodic Pension and Other Postretirement Benefit Costs | 6.65% | 5.65% | 5.87% |
Defined Benefit Plan, Year Health Care Trend Rate Reached and Beyond | 2032 | 2032 | 2030 |
Post Sixty Five Retirees [Member] | |||
Defined Benefit Plan, Health Care Cost Trend Rate, Net Periodic Pension and Other Postretirement Benefit Costs | 7.50% | 5.90% | 6.31% |
Defined Benefit Plan, Year Health Care Trend Rate Reached and Beyond | 2032 | 2032 | 2028 |
Other Postretirement Benefits Plan [Member] | Measurement Input Discount Rate Service Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5% | 3.20% | 2.98% |
Other Postretirement Benefits Plan [Member] | Measurement Input Discount Rate Interest Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5.09% | 2.31% | 1.86% |
Other Postretirement Benefits Plan [Member] | Other Postretirement Taxable Assets [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-Term Rate of Return on Plan Assets | 5.25% | 4.75% | 5% |
Pension Plan [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-Term Rate of Return on Plan Assets | 7% | 6.75% | 6.75% |
Pension Plan [Member] | Qualified Plan [Member] | Measurement Input Discount Rate Service Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5.26% | 3.07% | 2.81% |
Pension Plan [Member] | Qualified Plan [Member] | Measurement Input Discount Rate Interest Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5.16% | 2.49% | 2.08% |
Pension Plan [Member] | Nonqualified Plan [Member] | Measurement Input Discount Rate Service Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5.31% | 4.94% | 1.48% |
Pension Plan [Member] | Nonqualified Plan [Member] | Measurement Input Discount Rate Interest Costs [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 5.30% | 5.03% | 2.14% |
Minimum [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 0.0398% | 3.98% | 3.98% |
Minimum [Member] | Other Postretirement Benefits Plan [Member] | Other Postretirement Non Taxable Assets [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-Term Rate of Return on Plan Assets | 0.06% | 0.00058% | 0.06% |
Minimum [Member] | Pension Plan [Member] | Qualified Plan [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 0.0005% | 5.21% | |
Maximum [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 0.044% | 4.40% | 4.40% |
Maximum [Member] | Other Postretirement Benefits Plan [Member] | Other Postretirement Non Taxable Assets [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-Term Rate of Return on Plan Assets | 0.07% | 0.0675% | 0.0675% |
Maximum [Member] | Pension Plan [Member] | Qualified Plan [Member] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 0.00051% | 5.27% |
Retirement, Other Postretire_16
Retirement, Other Postretirement Benefits, And Defined Contribution Plans Contributions To Defined Contribution Plans (Details) - Defined Contribution Plans [Member] - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Entergy Arkansas [Member] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | $ 5,866 | $ 5,124 | $ 4,820 |
Entergy Louisiana [Member] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | 7,757 | 7,138 | 6,678 |
Entergy Mississippi [Member] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | 3,534 | 3,194 | 3,045 |
Entergy New Orleans [Member] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | 1,383 | 1,223 | 1,140 |
Entergy Texas [Member] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | $ 3,380 | $ 2,938 | $ 2,699 |
Stock-Based Compensation (Narra
Stock-Based Compensation (Narrative) (Details) - USD ($) | 1 Months Ended | 12 Months Ended | ||||||||
Jan. 27, 2022 | Jan. 31, 2023 | Jan. 31, 2022 | Jan. 31, 2021 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Jan. 26, 2023 | May 01, 2021 | May 03, 2019 | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 | $ 0.01 | |||||||
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 | $ 0.01 | |||||||
2019 Omnibus Incentive Plan [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares Available for Grant | 7,546,825 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares Authorized | 12,200,000 | |||||||||
Employee Stock Option | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested in Period, Fair Value | $ 6,000,000 | $ 6,000,000 | $ 5,000,000 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Expiration Period | 10 years | |||||||||
Percentage Of After Tax Net Profit To Be Retained By Executive Officer To Achieve Ownership Position | 75% | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 20.07 | $ 16.25 | $ 12.27 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercises in Period, Intrinsic Value | $ 2,000,000 | $ 20,000,000 | $ 2,000,000 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value | 31,447,529 | |||||||||
Share-Based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount | $ 5,000,000 | |||||||||
Share-Based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition | 1 year 7 months 6 days | |||||||||
Proceeds from Stock Options Exercised | $ 10,000,000 | |||||||||
Share-Based Payment Arrangement, Exercise of Option, Tax Benefit | $ 500,000 | |||||||||
Out of the money stock options of total stock options outstanding | 1,153,596 | |||||||||
Out of the money stock options of total stock options outstanding | 1,153,596 | |||||||||
Employee Stock Option | Out of the money options [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value | $ 0 | |||||||||
Long Term Performance Unit [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 126.39 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 481,001 | 521,838 | ||||||||
Long Term Performance Unit [Member] | 2019 Omnibus Incentive Plan [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Awards Granted, Fair Value | $ 20,000,000 | $ 35,000,000 | 32,000,000 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares Available for Grant | 143,212 | |||||||||
Long Term Performance Unit [Member] | 2022-2024 Long-Term Performance Unit Program [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Percent of performance measure based on relative total shareholder return | 80% | |||||||||
Percent of performance measure based on cumulative adjusted metric | 20% | |||||||||
Restricted Stock Units (RSUs) [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Awards Granted, Fair Value | $ 2,000,000 | $ 8,000,000 | 4,000,000 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 102.05 | |||||||||
Share-based Compensation Arrangement by Share-based Payment Award, Average Award Vesting Period | 38 months | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 139,500 | 132,407 | ||||||||
Share Based Compensation Arrangement By Share Based Payment Award, Equity Instruments Other Than Options, Period Expected For Vesting | 20 months | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 1,000,000 | $ 3,000,000 | 3,000,000 | |||||||
Restricted Stock [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Awards Granted, Fair Value | $ 41,000,000 | $ 39,000,000 | 40,000,000 | |||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 108.35 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 626,773 | 607,723 | ||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 33,000,000 | $ 34,000,000 | $ 32,000,000 | |||||||
Restricted Stock [Member] | 2019 Omnibus Incentive Plan [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares Available for Grant | 345,983 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 108.47 | |||||||||
Common Stock [Member] | 2017-2019 Long-Term Performance Unit Program [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 235,983 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 95.12 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 95.12 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 235,983 | |||||||||
Common Stock [Member] | 2018-2020 Long-Term Performance Unit Program [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 224,334 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 110.35 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 110.35 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 224,334 | |||||||||
Common Stock [Member] | 2019-2021 Long-Term Performance Unit Program [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 38,150 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 107.59 | |||||||||
Common Stock, Par or Stated Value Per Share | $ 107.59 | |||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Shares Issued in Period | 38,150 | |||||||||
Performance measure based on relative total shareholder return [Member] | Long Term Performance Unit [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 130.65 | |||||||||
Performance measure based on the credit measure [Member] | Long Term Performance Unit [Member] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | ||||||||||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 108.47 |
Stock-Based Compensation (Sched
Stock-Based Compensation (Schedule Of Financial Information Of Options) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Employee Stock Option | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested in Period, Fair Value | $ 6 | $ 6 | $ 5 |
Share-Based Payment Arrangement, Expense | 4.1 | 4.2 | 4.2 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 1.1 | 1.1 | 1.1 |
Share-Based Payment Arrangement, Amount Capitalized | 1.9 | 1.7 | 1.5 |
Restricted Stock Units (RSUs) [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Payment Arrangement, Expense | 2.8 | 2 | 1.9 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 0.7 | 0.5 | 0.5 |
Share-Based Payment Arrangement, Amount Capitalized | 1.2 | 0.8 | 0.7 |
Restricted Stock [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Payment Arrangement, Expense | 22.2 | 23.2 | 24.7 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 5.7 | 5.9 | 6.3 |
Share-Based Payment Arrangement, Amount Capitalized | 9.7 | 9.2 | 9.3 |
Long Term Performance Unit [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Payment Arrangement, Expense | 11.1 | 16 | 14.5 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 2.8 | 4.1 | 3.7 |
Share-Based Payment Arrangement, Amount Capitalized | $ 5.2 | $ 6.7 | $ 5.8 |
Stock-Based Compensation (Stock
Stock-Based Compensation (Stock Option Weighted-Average Assumptions Used In Determining Fair Values) (Details) - Employee Stock Option - USD ($) | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Fair Value Assumptions, Expected Volatility Rate | 24.89% | 24.27% | 23.93% |
Share-Based Compensation Arrangement by Share-Based Payment Award, Fair Value Assumptions, Expected Term | 6 years 10 months 20 days | 6 years 11 months 1 day | 6 years 11 months 4 days |
Share-Based Compensation Arrangement by Share-Based Payment Award, Fair Value Assumptions, Risk Free Interest Rate | 3.51% | 1.77% | 0.74% |
Share-Based Compensation Arrangement by Share-Based Payment Award, Fair Value Assumptions, Expected Dividend Rate | 4% | 4% | 4% |
Share-Based Compensation Arrangement by Share-Based Payment Award, Fair Value Assumptions, Expected Dividend Payments | $ 4.34 | $ 4.10 | $ 3.86 |
Stock-Based Compensation (Summa
Stock-Based Compensation (Summary Of Stock Option Activity) (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Employee Stock Option | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number, Beginning Balance | 2,776,355 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Exercise Price, Beginning Balance | $ 96.30 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Net of Forfeitures | 281,874 | ||
Share-Based Compensation Arrangements by Share-Based Payment Award, Options, Grants in Period, Weighted Average Exercise Price | $ 108.47 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercises in Period | (111,929) | ||
Share-Based Compensation Arrangements by Share-Based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price | $ 85.69 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Forfeitures and Expirations in Period | (47,592) | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 110.40 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number, Ending Balance | 2,898,708 | 2,776,355 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Exercise Price, Ending Balance | $ 97.66 | $ 96.30 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term | 5 years 7 months 28 days | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercisable, Number | 2,191,916 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercisable, Weighted Average Exercise Price | $ 94.94 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercisable, Intrinsic Value | $ 30,475,161 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term | 4 years 9 months 29 days | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 20.07 | $ 16.25 | $ 12.27 |
Restricted Stock Units (RSUs) [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 139,500 | 132,407 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period | 22,547 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period | 6,142 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeited in Period | 9,312 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 105.11 | $ 105.75 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | 102.05 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | 110.33 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ 103.37 | ||
Restricted Stock [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 626,773 | 607,723 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period | 373,741 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period | 294,145 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeited in Period | 60,546 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 106.80 | $ 107.55 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | 108.35 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | 110.54 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ 105.64 | ||
Long Term Performance Unit [Member] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items] | |||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 481,001 | 521,838 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period | 156,627 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period | 38,150 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeited in Period | 159,314 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 121.12 | $ 129.94 | |
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | 126.39 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | 162.14 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ 145.35 |
Stock-Based Compensation (Sum_2
Stock-Based Compensation (Summary Of Stock Options Outstanding Information) (Details) - Employee Stock Option | 12 Months Ended |
Dec. 31, 2023 $ / shares shares | |
Share-Based Payment Arrangement, Option, Exercise Price Range [Line Items] | |
Share-Based Payment Arrangement, Option, Exercise Price Range, Lower Range Limit | $ 63.17 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Upper Range Limit | $ 131.72 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Outstanding | shares | 2,898,708 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Remaining Contractual Term | 5 years 7 months 28 days |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Exercise Price | $ 97.66 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Exercisable | shares | 2,191,916 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Exercisable, Weighted Average Exercise Price | $ 94.94 |
Range Of Exercise Prices2 [Member] | |
Share-Based Payment Arrangement, Option, Exercise Price Range [Line Items] | |
Share-Based Payment Arrangement, Option, Exercise Price Range, Lower Range Limit | 80 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Upper Range Limit | $ 99.99 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Outstanding | shares | 972,138 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Remaining Contractual Term | 5 years 5 months 12 days |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Exercise Price | $ 92.30 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Exercisable | shares | 814,286 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Exercisable, Weighted Average Exercise Price | $ 91.61 |
Range Of Exercise Prices3 [Member] | |
Share-Based Payment Arrangement, Option, Exercise Price Range [Line Items] | |
Share-Based Payment Arrangement, Option, Exercise Price Range, Lower Range Limit | 100 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Upper Range Limit | $ 119.99 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Outstanding | shares | 685,327 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Remaining Contractual Term | 8 years 5 months 23 days |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Exercise Price | $ 109.14 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Exercisable | shares | 136,387 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Exercisable, Weighted Average Exercise Price | $ 109.59 |
Range Of Exercise Prices1 [Member] | |
Share-Based Payment Arrangement, Option, Exercise Price Range [Line Items] | |
Share-Based Payment Arrangement, Option, Exercise Price Range, Lower Range Limit | 63.17 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Upper Range Limit | $ 79.99 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Outstanding | shares | 772,974 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Remaining Contractual Term | 3 years 2 months 4 days |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Exercise Price | $ 73.58 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Exercisable | shares | 772,974 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Exercisable, Weighted Average Exercise Price | $ 73.58 |
Range Of Exercise Prices4 [Member] | |
Share-Based Payment Arrangement, Option, Exercise Price Range [Line Items] | |
Share-Based Payment Arrangement, Option, Exercise Price Range, Lower Range Limit | 120 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Upper Range Limit | $ 131.72 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Outstanding | shares | 468,269 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Remaining Contractual Term | 6 years 29 days |
Share-Based Payment Arrangement, Option, Exercise Price Range, Outstanding, Weighted Average Exercise Price | $ 131.72 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Shares Exercisable | shares | 468,269 |
Share-Based Payment Arrangement, Option, Exercise Price Range, Exercisable, Weighted Average Exercise Price | $ 131.72 |
Business Segment Information Na
Business Segment Information Narrative (Details) - USD ($) $ in Thousands | 1 Months Ended | 3 Months Ended | 12 Months Ended | ||||||||
Mar. 31, 2023 | Jun. 30, 2022 | May 31, 2022 | May 31, 2021 | Dec. 31, 2023 | Sep. 30, 2023 | Mar. 31, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Segment Reporting Information [Line Items] | |||||||||||
Restructuring Charges | $ 3,000 | $ 13,000 | |||||||||
Restructuring Reserve | 0 | 37,000 | $ 159,000 | ||||||||
Asset Impairment Charges | $ 42,679 | (163,464) | 263,625 | ||||||||
Indian Point Energy Center [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property | $ 340,000 | ||||||||||
Palisades [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property | $ 166,000 | ||||||||||
System Energy [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Reduction to income tax expense | 1,000 | ||||||||||
Regulatory charge related to System Energy settlement | 551,000 | $ 40,000 | |||||||||
Regulatory charge related to System Energy settlement - net of tax | 413,000 | ||||||||||
Entergy Louisiana [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Reduction to income tax expense | 42,000 | ||||||||||
Regulatory charge recorded as a result of reduction in income tax expense | $ 103,000 | $ 224,000 | $ 103,000 | ||||||||
Regulatory charge recorded as a result of reduction in income tax expense, net of tax | $ 76,000 | 165,000 | 76,000 | ||||||||
Reduction to income tax expense - net, offset by other tax charges | 129,000 | ||||||||||
Regulatory charge to reflect credits expected to be provided to customers as a result of the resolution of the 2016-2018 IRS audit, net of tax | 28,000 | ||||||||||
Entergy Arkansas [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Reduction to income tax expense | 9,000 | ||||||||||
Asset Impairment Charges | 78,434 | 0 | 0 | ||||||||
Utility [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Asset Impairment Charges | 79,962 | 0 | 0 | ||||||||
Reduction in income tax expense as a result of the resolution of the 2016-2018 IRS audit | 568,000 | ||||||||||
Regulatory charge to reflect credits expected to be provided to customers as a result of the resolution of the 2016-2018 IRS audit | 98,000 | ||||||||||
Regulatory charge to reflect credits expected to be provided to customers as a result of the resolution of the 2016-2018 IRS audit, net of tax | 72,000 | ||||||||||
Utility [Member] | System Energy [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Regulatory charge related to System Energy settlement | 551,000 | ||||||||||
Regulatory charge related to System Energy settlement - net of tax | 413,000 | ||||||||||
Utility [Member] | Entergy Louisiana [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Reduction to income tax expense | 283,000 | ||||||||||
Regulatory charge recorded as a result of reduction in income tax expense | 224,000 | 103,000 | |||||||||
Regulatory charge recorded as a result of reduction in income tax expense, net of tax | $ 165,000 | 76,000 | |||||||||
Reduction to income tax expense - net, offset by other tax charges | $ 129,000 | ||||||||||
Reversal of regulatory liability for excess ADIT | 106,000 | ||||||||||
Utility [Member] | Entergy Arkansas [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Asset Impairment Charges | $ 78,000 | ||||||||||
Asset Impairment Charges, net of tax | $ 59,000 | ||||||||||
Corporate and Other [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Asset Impairment Charges | $ (37,283) | (163,464) | 263,625 | ||||||||
Reduction in income tax expense as a result of the resolution of the 2016-2018 IRS audit | $ 275,000 | ||||||||||
Corporate and Other [Member] | Indian Point Energy Center [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property | 340,000 | ||||||||||
Reduction to income tax expense | $ 268,000 | ||||||||||
Corporate and Other [Member] | Palisades [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property | 166,000 | ||||||||||
Reduction to income tax expense | $ 130,000 | ||||||||||
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Restructuring Charges | 3,000 | 12,000 | |||||||||
Restructuring Reserve | $ 0 | $ 37,000 | $ 145,000 |
Business Segment Information Se
Business Segment Information Segment Financial Information (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Segment Financial Information Abstract | |||
Operating revenues | $ 12,147,412 | $ 13,764,237 | $ 11,742,896 |
Asset Impairment Charges | 42,679 | (163,464) | 263,625 |
Depreciation, Depletion and Amortization | 2,051,677 | 1,985,099 | 1,990,697 |
Investment Income, Net | 162,726 | (75,581) | 430,466 |
Interest expense | 1,006,406 | 912,237 | 834,694 |
Income Tax Expense (Benefit) | (690,535) | (38,978) | 191,374 |
Consolidated net income | 2,362,310 | 1,097,138 | 1,118,719 |
Total assets | 59,703,396 | 58,595,191 | 59,454,242 |
Segment, Expenditure, Addition to Long-Lived Assets | 4,746,719 | 5,396,127 | 6,422,112 |
Utility [Member] | |||
Segment Financial Information Abstract | |||
Operating revenues | 12,022,944 | 13,420,804 | 11,044,674 |
Asset Impairment Charges | 79,962 | 0 | 0 |
Depreciation, Depletion and Amortization | 2,045,254 | 1,941,653 | 1,823,389 |
Investment Income, Net | 443,751 | 145,968 | 442,817 |
Interest expense | 816,643 | 750,175 | 692,004 |
Income Tax Expense (Benefit) | (374,847) | (34,263) | 264,209 |
Consolidated net income | 2,510,904 | 1,398,580 | 1,488,487 |
Total assets | 63,887,038 | 61,399,243 | 59,733,625 |
Segment, Expenditure, Addition to Long-Lived Assets | 4,745,918 | 5,382,243 | 6,409,855 |
Corporate and Other [Member] | |||
Segment Financial Information Abstract | |||
Operating revenues | 124,509 | 343,461 | 698,251 |
Asset Impairment Charges | (37,283) | (163,464) | 263,625 |
Depreciation, Depletion and Amortization | 6,423 | 43,446 | 167,308 |
Investment Income, Net | 18,660 | (35,293) | 115,273 |
Interest expense | 190,468 | 162,300 | 142,693 |
Income Tax Expense (Benefit) | (315,688) | (4,715) | (72,835) |
Consolidated net income | 150,385 | (115,425) | (242,146) |
Total assets | 836,598 | 884,442 | 1,718,638 |
Segment, Expenditure, Addition to Long-Lived Assets | 801 | 13,884 | 12,257 |
Eliminations [Member] | |||
Segment Financial Information Abstract | |||
Operating revenues | (41) | (28) | (29) |
Asset Impairment Charges | 0 | 0 | 0 |
Depreciation, Depletion and Amortization | 0 | 0 | 0 |
Investment Income, Net | (299,685) | (186,256) | (127,624) |
Interest expense | (705) | (238) | (3) |
Income Tax Expense (Benefit) | 0 | 0 | 0 |
Consolidated net income | (298,979) | (186,017) | (127,622) |
Total assets | (5,020,240) | (3,688,494) | (1,998,021) |
Segment, Expenditure, Addition to Long-Lived Assets | $ 0 | $ 0 | $ 0 |
Business Segment Information _2
Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Charges | $ 3 | $ 13 | |
Payments for Restructuring | 40 | 135 | |
Restructuring Reserve | 0 | 37 | $ 159 |
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Charges | 3 | 12 | |
Payments for Restructuring | 40 | 120 | |
Restructuring Reserve | 0 | 37 | 145 |
Economic Development Costs [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Charges | 0 | 1 | |
Payments for Restructuring | 0 | 15 | |
Restructuring Reserve | $ 0 | $ 0 | $ 14 |
Acquisitions, Dispositions, and
Acquisitions, Dispositions, and Impairment of Long-Lived Assets Narrative (Details) | 1 Months Ended | 6 Months Ended | 12 Months Ended | |||||||||||||||||
Feb. 29, 2024 USD ($) | Oct. 31, 2023 USD ($) | Apr. 30, 2023 USD ($) | Jun. 30, 2022 USD ($) | May 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | Jun. 30, 2021 USD ($) MW | May 31, 2021 USD ($) | Jun. 30, 2020 MW | Apr. 30, 2020 USD ($) | Apr. 30, 2019 | Mar. 31, 2019 MW | Nov. 30, 2018 MW | Jul. 31, 2018 | Jun. 30, 2024 USD ($) | Dec. 31, 2023 USD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | Jun. 28, 2022 USD ($) | May 28, 2021 USD ($) | |
Business Acquisition [Line Items] | ||||||||||||||||||||
Payments to Acquire Productive Assets | $ 35,094,000 | $ 106,193,000 | $ 168,304,000 | |||||||||||||||||
Asset Retirement Obligation | $ 4,757,100,000 | 4,505,800,000 | 4,271,500,000 | 4,757,100,000 | ||||||||||||||||
Public Utilities, Property, Plant and Equipment, Net | 43,834,329,000 | 42,477,124,000 | ||||||||||||||||||
Entergy Arkansas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Asset Retirement Obligation | 1,390,400,000 | 1,560,100,000 | 1,472,700,000 | 1,390,400,000 | ||||||||||||||||
Public Utilities, Property, Plant and Equipment, Net | 9,373,934,000 | 8,941,958,000 | ||||||||||||||||||
Entergy Mississippi [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Asset Retirement Obligation | 10,300,000 | 8,200,000 | 7,800,000 | 10,300,000 | ||||||||||||||||
Public Utilities, Property, Plant and Equipment, Net | 5,248,453,000 | 4,985,254,000 | ||||||||||||||||||
Entergy Texas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Payments to Acquire Productive Assets | 0 | 0 | 36,534,000 | |||||||||||||||||
Proceeds from Sale of Productive Assets | 11,000,000 | 0 | 67,920,000 | |||||||||||||||||
Asset Retirement Obligation | 8,500,000 | 11,700,000 | 11,100,000 | $ 8,500,000 | ||||||||||||||||
Public Utilities, Property, Plant and Equipment, Net | $ 6,425,128,000 | 5,613,200,000 | ||||||||||||||||||
Palisades [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Decommissioning Fund Investments, Fair Value | $ 552,000,000 | |||||||||||||||||||
Proceeds from Sale of Productive Assets | $ 1,000 | |||||||||||||||||||
Asset Retirement Obligation | 708,000,000 | |||||||||||||||||||
Percentage of Undivided Ownership Interest | 100% | |||||||||||||||||||
Gain (Loss) on Disposition of Assets | 166,000,000 | |||||||||||||||||||
Gain (Loss) on Disposition of Assets (Net-Of-Tax) | $ 130,000,000 | |||||||||||||||||||
Public Utilities, Property, Plant and Equipment, Net | $ 0 | |||||||||||||||||||
Montgomery County Power Station [Member] | Entergy Texas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Proceeds from Sale of Productive Assets | $ 68,000,000 | |||||||||||||||||||
Percentage of Undivided Ownership Interest | 7.56% | |||||||||||||||||||
Searcy Solar Facility [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Capacity Of Power Plant Unit | MW | 100 | |||||||||||||||||||
Searcy Solar Facility [Member] | Entergy Arkansas [Member] | AR Searcy Partnership, LLC [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Payments to Acquire Productive Assets | $ 133,000,000 | $ 1,000,000 | ||||||||||||||||||
Indian Point Energy Center [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Decommissioning Fund Investments, Fair Value | $ 2,387,000,000 | |||||||||||||||||||
Asset Retirement Obligation | $ 1,996,000,000 | |||||||||||||||||||
Percentage of Undivided Ownership Interest | 100% | |||||||||||||||||||
Gain (Loss) on Disposition of Assets | $ 340,000,000 | |||||||||||||||||||
Gain (Loss) on Disposition of Assets (Net-Of-Tax) | $ 268,000,000 | |||||||||||||||||||
Hardin County Peaking Facility [Member] | Entergy Texas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Capacity Of Power Plant Unit | MW | 147 | |||||||||||||||||||
Payments to Acquire Productive Assets | $ 37,000,000 | |||||||||||||||||||
Sunflower Solar facility [Member] | Entergy Mississippi [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Conditional cap on level of recoverable costs | $ 136,000,000 | |||||||||||||||||||
Capacity Of Power Plant Unit | MW | 100 | |||||||||||||||||||
Sunflower Solar facility [Member] | Entergy Mississippi [Member] | MS Sunflower Partnership, LLC [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Payments to Acquire Productive Assets | $ 5,000,000 | $ 30,000,000 | $ 105,000,000 | |||||||||||||||||
Walnut Bend Solar facility | Entergy Arkansas [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Capacity Of Power Plant Unit | MW | 100 | |||||||||||||||||||
Walnut Bend Solar facility | Entergy Arkansas [Member] | Subsequent Event [Member] | ||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||
Payments to Acquire Productive Assets | $ 170,000,000 | |||||||||||||||||||
Expected payments to acquire productive assets | $ 20,000,000 |
Risk Management and Fair Valu_3
Risk Management and Fair Values Narrative (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 USD ($) GWh MMBTU | Dec. 31, 2021 USD ($) | Dec. 31, 2022 USD ($) | |
Risk Management and Fair Values (Textual) [Abstract] | |||
Derivative Instruments Gain Loss Reclassified From Accumulated O C I Into Income Effective Portion Tax | $ 8 | ||
Collateral Already Posted, Aggregate Fair Value | $ 8 | ||
Utility [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | $ 2 | 3 | |
Gas Hedge Contracts [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 14,798,500 | ||
Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Volume of Financial Transmission Rights Outstanding | GWh | 62,809 | ||
Electricity Futures Forwards Swaps And Options [Member] | Cash Flow Hedging [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Unrealized Gain (Loss) on Derivatives | $ 2 | ||
Derivative Instrument, Gain (Loss) Reclassified from AOCI into Income, Effective Portion, Statement of Income or Comprehensive Income [Extensible Enumeration] | Revenue from Contract with Customer, Excluding Assessed Tax | ||
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | $ 1.2 | ||
Volume of Financial Transmission Rights Outstanding | GWh | 15,385 | ||
Entergy Louisiana [Member] | Gas Hedge Contracts [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 1,820,000 | ||
Maximum Length of Time Hedged in Cash Flow Hedge | 3 months | ||
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | $ 0.5 | ||
Volume of Financial Transmission Rights Outstanding | GWh | 26,990 | ||
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 12,491,700 | ||
Maximum Length of Time Hedged in Cash Flow Hedge | 10 months | ||
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | $ 0.3 | 0.2 | |
Volume of Financial Transmission Rights Outstanding | GWh | 8,250 | ||
Entergy New Orleans [Member] | Gas Hedge Contracts [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 486,800 | ||
Maximum Length of Time Hedged in Cash Flow Hedge | 3 months | ||
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | 0.2 | ||
Volume of Financial Transmission Rights Outstanding | GWh | 2,478 | ||
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | |||
Risk Management and Fair Values (Textual) [Abstract] | |||
Letters of Credit Outstanding, Amount | $ 0.1 | $ 2.4 | |
Volume of Financial Transmission Rights Outstanding | GWh | 9,611 |
Risk Management and Fair Valu_4
Risk Management and Fair Values Fair Values Of Derivative Instruments (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Collateral Already Posted, Aggregate Fair Value | $ 8 | |
Utility [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 2 | 3 |
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | 13 | |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | |
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | |
Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Utility [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | 21 | $ 21 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | $ (2) |
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 3 | |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | |
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Other Assets, Noncurrent | |
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 11 | $ 25 |
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 |
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 11 | $ 25 |
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current |
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | |
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | |
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration] | Other Assets, Noncurrent | |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 0.5 | |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 13.1 | |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | |
Entergy Louisiana [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 9.8 | 7.7 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | (0.4) |
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | 3.4 | |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | |
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | 0.4 | |
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | |
Derivative Liability, Subject to Master Netting Arrangement, before Offset | 0.4 | |
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 1.2 | |
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Entergy Arkansas [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 6 | $ 10.3 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | $ 0 |
Entergy Mississippi [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 0.3 | $ 0.2 |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Entergy Mississippi [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 1.4 | $ 0.6 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 |
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | 10.1 | 24 |
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 |
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 10.1 | $ 24 |
Entergy New Orleans [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current |
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 0.2 | |
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Entergy New Orleans [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 1.1 | $ 0.8 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 |
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | 0.6 | 1.5 |
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 |
Derivative Liability, Subject to Master Netting Arrangement, before Offset | 0.6 | 1.5 |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Letters of Credit Outstanding, Amount | $ 0.1 | $ 2.4 |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current |
Entergy Texas [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | ||
Derivative Asset, Subject to Master Netting Arrangement, before Offset | $ 2.7 | $ 1.2 |
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0.3 | $ 1.1 |
Risk Management and Fair Valu_5
Risk Management and Fair Values Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Derivative Instruments, Gain (Loss) [Line Items] | |||
Collateral Already Posted, Aggregate Fair Value | $ 8 | ||
Fuel Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used |
Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Other Operating Revenues [Member] | Electricity Futures Forwards Swaps And Options [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Revenue from Contract with Customer, Excluding Assessed Tax | ||
Entergy Louisiana [Member] | Fuel Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used |
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Entergy Mississippi [Member] | Fuel Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used |
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Entergy New Orleans [Member] | Fuel Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used |
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Entergy Texas [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power | Utilities Operating Expense, Purchased Power |
Risk Management and Fair Valu_6
Risk Management and Fair Values Assets And Liabilities At Fair Value On A Recurring Basis (Details) - USD ($) $ in Thousands | Dec. 31, 2023 | Dec. 31, 2022 |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | $ 60,939 | $ 108,874 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 323,000 | 402,000 |
Restricted Cash and Cash Equivalents, Current | 8,000 | 13,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 5,277,000 | 4,681,000 |
Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 11,000 | 25,000 |
Equity Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 24,000 | 24,000 |
Common trust funds valued using Net Asset Value [Domain] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 3,070,000 | 2,442,000 |
Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 21,000 | 19,000 |
Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 16,000 | |
Debt Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 1,770,000 | 1,656,000 |
Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 61,000 | 109,000 |
Equity Securities, FV-NI, Current | 24,000 | 24,000 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 323,000 | 402,000 |
Restricted Cash and Cash Equivalents, Current | 8,000 | 13,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 611,000 | 534,000 |
Assets, Fair Value Disclosure | 1,027,000 | 1,095,000 |
Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 11,000 | 25,000 |
Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 13,000 | |
Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 1,159,000 | 1,122,000 |
Assets, Fair Value Disclosure | 1,159,000 | 1,125,000 |
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 3,000 | |
Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 0 | 0 |
Assets, Fair Value Disclosure | 21,000 | 19,000 |
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 21,000 | 19,000 |
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | |
Entergy New Orleans [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 4,437 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 78,700 | 75,000 |
Restricted Cash and Cash Equivalents, Current | 2,426 | 2,235 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 82,200 | 82,400 |
Entergy New Orleans [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 600 | 1,500 |
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 1,100 | 800 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 4,400 | |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 78,700 | 75,000 |
Restricted Cash and Cash Equivalents, Current | 2,400 | 2,200 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 81,100 | 81,600 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 600 | 1,500 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 0 | 0 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,100 | 800 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 1,100 | 800 |
Entergy Mississippi [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 6,600 | 16,953 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 700 | 33,500 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 8,700 | 51,100 |
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 10,100 | 24,000 |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 1,400 | 600 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 6,600 | 17,000 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 700 | 33,500 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 7,300 | 50,500 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 10,100 | 24,000 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,400 | 600 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 1,400 | 600 |
Entergy Louisiana [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 517 | 6,295 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 243,800 | 293,400 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,361,500 | 2,102,600 |
Entergy Louisiana [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 400 | |
Entergy Louisiana [Member] | Equity Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 14,600 | 16,800 |
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 1,304,700 | 1,037,200 |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 9,800 | 7,300 |
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 16,500 | |
Entergy Louisiana [Member] | Debt Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 788,100 | 725,100 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 500 | 6,300 |
Equity Securities, FV-NI, Current | 14,600 | 16,800 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 243,800 | 293,400 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 271,700 | 209,400 |
Assets, Fair Value Disclosure | 530,600 | 539,000 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 400 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 13,100 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 516,400 | 515,700 |
Assets, Fair Value Disclosure | 516,400 | 519,100 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 3,400 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 0 | 0 |
Assets, Fair Value Disclosure | 9,800 | 7,300 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Liability | 0 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 9,800 | 7,300 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | |
Entergy Texas [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 20,489 | 2,997 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 5,195 | 10,879 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 28,100 | 14,000 |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 2,400 | 100 |
Entergy Texas [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 20,500 | 3,000 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 5,200 | 10,900 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 25,700 | 13,900 |
Entergy Texas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 0 | 0 |
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,400 | 100 |
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 2,400 | 100 |
Entergy Arkansas [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 3,112 | 3,367 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,423,100 | 1,213,600 |
Entergy Arkansas [Member] | Equity Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 6,400 | 4,500 |
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 910,700 | 724,700 |
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 6,000 | 10,300 |
Entergy Arkansas [Member] | Debt Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 496,900 | 470,700 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 3,100 | 3,400 |
Equity Securities, FV-NI, Current | 6,400 | 4,500 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 129,900 | 126,800 |
Assets, Fair Value Disclosure | 139,400 | 134,700 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 367,000 | 343,900 |
Assets, Fair Value Disclosure | 367,000 | 343,900 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 0 | 0 |
Assets, Fair Value Disclosure | 6,000 | 10,300 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 6,000 | 10,300 |
System Energy [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | 2,862 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,342,300 | 1,145,800 |
System Energy [Member] | Equity Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 2,700 | 2,800 |
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 854,400 | 680,400 |
System Energy [Member] | Debt Securities [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 485,200 | 459,700 |
System Energy [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 2,900 | |
Equity Securities, FV-NI, Current | 2,700 | 2,800 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 209,500 | 197,500 |
Assets, Fair Value Disclosure | 212,200 | 203,200 |
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | |
Equity Securities, FV-NI, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 275,700 | 262,200 |
Assets, Fair Value Disclosure | 275,700 | 262,200 |
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 0 | |
Equity Securities, FV-NI, Current | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Debt Securities | 0 | 0 |
Assets, Fair Value Disclosure | $ 0 | $ 0 |
Risk Management and Fair Valu_7
Risk Management and Fair Values Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss) | $ 0 | $ 0 | $ 0 | |
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 84 | 175 | 162 | |
Issuances of financial transmission rights | 42 | 16 | 12 | |
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings | 0 | 0 | 0 | |
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (124) | (176) | (179) | |
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 21 | 19 | 4 | $ 9 |
Electricity Futures Forwards Swaps And Options [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss) | 2 | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 0 | |||
Issuances of financial transmission rights | 0 | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings | (2) | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (38) | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 0 | $ 38 | ||
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 0.9 | 109.1 | ||
Issuances of financial transmission rights | 20.6 | 5.4 | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (25.8) | (106.5) | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 6 | 10.3 | 2.3 | |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 44.8 | 49.9 | ||
Issuances of financial transmission rights | 18.1 | 5.3 | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (60.4) | (48.5) | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 9.8 | 7.3 | 0.6 | |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 13.2 | 9.9 | ||
Issuances of financial transmission rights | 1.3 | 0.8 | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (13.7) | (10.4) | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 1.4 | 0.6 | 0.3 | |
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 5.3 | 3.6 | ||
Issuances of financial transmission rights | 1.4 | 0.8 | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (6.4) | (3.7) | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 1.1 | 0.8 | 0.1 | |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation, Recurring Basis, Asset And Liability, Calculation [Roll Forward] | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 19.4 | 1.7 | ||
Issuances of financial transmission rights | 0.2 | 3.9 | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (17.3) | (6.3) | ||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | $ 2.4 | $ 0.1 | $ 0.8 |
Decommissioning Trust Funds (Na
Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Jun. 28, 2022 | |
Decommissioning Trust Funds (Textual) [Abstract] | ||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 1,885 | $ 1,852 | ||
Average Coupon Rate of Debt Securities Percentage | 3.48% | |||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 661 | 889 | $ 1,465 | |
Average Duration of Debt Securities in Years | 6 years 4 months 9 days | |||
Average Maturity of Debt Securities, Years | 10 years 9 months 25 days | |||
Debt Securities, Available-for-Sale, Realized Gain | $ 1 | 2 | 29 | |
Debt Securities, Available-for-Sale, Realized Loss | 37 | 46 | 17 | |
Equity Securities, FV-NI, Unrealized Gain | 591 | |||
Entergy Arkansas [Member] | ||||
Decommissioning Trust Funds (Textual) [Abstract] | ||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 548.1 | 539.8 | ||
Average Coupon Rate of Debt Securities Percentage | 2.66% | |||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 28.5 | 42.1 | 57.6 | |
Average Duration of Debt Securities in Years | 6 years 7 days | |||
Average Maturity of Debt Securities, Years | 7 years 7 months 20 days | |||
Debt Securities, Available-for-Sale, Realized Gain | $ 0.1 | 0.1 | 2.5 | |
Debt Securities, Available-for-Sale, Realized Loss | 2 | 2.6 | 0.6 | |
Equity Securities, FV-NI, Unrealized Gain | $ 175 | |||
Entergy Louisiana [Member] | ||||
Percentage Interest in River Bend | 30% | |||
Decommissioning Trust Funds (Textual) [Abstract] | ||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 813.9 | 789.1 | ||
Average Coupon Rate of Debt Securities Percentage | 3.91% | |||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 318.6 | 362.2 | 303.4 | |
Average Duration of Debt Securities in Years | 6 years 6 months 10 days | |||
Average Maturity of Debt Securities, Years | 13 years 1 month 28 days | |||
Debt Securities, Available-for-Sale, Realized Gain | $ 0.5 | 1.3 | 6.8 | |
Debt Securities, Available-for-Sale, Realized Loss | 20.9 | 23 | 4.1 | |
Equity Securities, FV-NI, Unrealized Loss | 251.3 | |||
System Energy [Member] | ||||
Decommissioning Trust Funds (Textual) [Abstract] | ||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 523.2 | 522.7 | ||
Average Coupon Rate of Debt Securities Percentage | 3.63% | |||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 314.3 | 209.4 | 513.8 | |
Average Duration of Debt Securities in Years | 6 years 5 months 8 days | |||
Average Maturity of Debt Securities, Years | 10 years 3 months 7 days | |||
Debt Securities, Available-for-Sale, Realized Gain | $ 0.6 | 0.2 | 9.3 | |
Debt Securities, Available-for-Sale, Realized Loss | 14.2 | $ 10.7 | $ 4 | |
Equity Securities, FV-NI, Unrealized Loss | $ 164.2 | |||
Palisades [Member] | ||||
Decommissioning Fund Investments, Fair Value | $ 552 |
Decommissioning Trust Funds (Se
Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Debt Securities, Available-for-Sale [Line Items] | ||
Total | $ 1,770 | $ 1,655 |
Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 1,770 | 1,655 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 19 | 4 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 134 | 201 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 788.1 | 725.1 |
Entergy Louisiana [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 788.1 | 725.1 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 11.7 | 3.5 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 37.4 | 67.5 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 496.9 | 470.7 |
Entergy Arkansas [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 496.9 | 470.7 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 2.4 | 0.2 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 53.6 | 69.3 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 485.2 | 459.7 |
System Energy [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Total | 485.2 | 459.7 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 4.5 | 0.7 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | $ 42.5 | $ 63.7 |
Decommissioning Trust Funds (Av
Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | $ 134 | $ 201 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 134 | 840 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 999 | 666 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 1,133 | 1,506 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 6 | 63 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 128 | 138 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 53.6 | 69.3 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 22.5 | 197.6 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 403.4 | 260.1 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 425.9 | 457.7 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 0.4 | 18.8 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 53.2 | 50.5 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 37.4 | 67.5 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 69.8 | 409.9 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 356.1 | 207.5 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 425.9 | 617.4 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 0.9 | 24.6 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 36.5 | 42.9 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 42.5 | 63.7 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 42.1 | 231.9 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 239.1 | 198 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 281.2 | 429.9 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 4.5 | 19.2 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | $ 38 | $ 44.5 |
Decommissioning Trust Funds (Fa
Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions | Dec. 31, 2023 | Dec. 31, 2022 |
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Less than 1 year | $ 82 | $ 62 |
1 year - 5 years | 517 | 520 |
5 years - 10 years | 504 | 461 |
10 years - 15 years | 121 | 117 |
15 years - 20 years | 179 | 161 |
20 years+ | 367 | 334 |
Total | 1,770 | 1,655 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Less than 1 year | 45.3 | 21.2 |
1 year - 5 years | 132.2 | 159.7 |
5 years - 10 years | 205.7 | 191.7 |
10 years - 15 years | 39.9 | 38 |
15 years - 20 years | 49.6 | 42.6 |
20 years+ | 24.2 | 17.5 |
Total | 496.9 | 470.7 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Less than 1 year | 31.4 | 33.6 |
1 year - 5 years | 181.6 | 159.1 |
5 years - 10 years | 170 | 161.7 |
10 years - 15 years | 70.2 | 67.1 |
15 years - 20 years | 90.2 | 83.3 |
20 years+ | 244.7 | 220.3 |
Total | 788.1 | 725.1 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Less than 1 year | 5.3 | 6.8 |
1 year - 5 years | 203.4 | 201.7 |
5 years - 10 years | 128.6 | 107.1 |
10 years - 15 years | 10.7 | 11.7 |
15 years - 20 years | 38.8 | 35 |
20 years+ | 98.4 | 97.4 |
Total | $ 485.2 | $ 459.7 |
Variable Interest Entities (Det
Variable Interest Entities (Details) - USD ($) $ in Thousands | 12 Months Ended | ||||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | Jun. 30, 2023 | Mar. 31, 2023 | |
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | $ 59,703,396 | $ 58,595,191 | $ 59,454,242 | ||
System Energy [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 4,312,363 | 4,214,146 | |||
System Energy [Member] | Grand Gulf [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Payments on lease including interest | 17,200 | 17,200 | $ 17,200 | ||
Entergy Arkansas [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 13,672,858 | 13,006,576 | |||
Members' Equity Attributable to Noncontrolling Interest | 21,599 | 27,825 | |||
Members' Equity Attributable to Noncontrolling Interest | 21,599 | 27,825 | |||
Entergy Arkansas [Member] | AR Searcy Partnership, LLC [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 134,000 | 138,300 | |||
Ownership Interest in Partnership, Carrying Value | 111,200 | 109,000 | |||
Members' Equity Attributable to Noncontrolling Interest | 21,599 | 27,825 | |||
Members' Equity Attributable to Noncontrolling Interest | 21,599 | 27,825 | |||
Entergy Mississippi [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 6,228,006 | 6,078,764 | |||
Members' Equity Attributable to Noncontrolling Interest | 18,753 | 3,347 | |||
Members' Equity Attributable to Noncontrolling Interest | 18,753 | 3,347 | |||
Entergy Mississippi [Member] | MS Sunflower Partnership, LLC [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 163,200 | 154,500 | |||
Ownership Interest in Partnership, Carrying Value | 128,400 | 117,200 | |||
Members' Equity Attributable to Noncontrolling Interest | 18,753 | 3,347 | |||
Members' Equity Attributable to Noncontrolling Interest | 18,753 | 3,347 | |||
Entergy Louisiana [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Assets | 29,109,470 | 28,144,555 | |||
LURC's beneficial interest in the storm trust, percentage | 1% | 1% | |||
Members' Equity Attributable to Noncontrolling Interest | 45,107 | 31,735 | |||
Members' Equity Attributable to Noncontrolling Interest | $ 45,107 | 31,735 | |||
LURC's beneficial interest in the storm trust, percentage | 1% | 1% | |||
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
LURC's beneficial interest in the storm trust, percentage | 1% | ||||
LURC's beneficial interest in the storm trust, percentage | 1% | ||||
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
LURC's beneficial interest in the storm trust, percentage | 1% | ||||
LURC's beneficial interest in the storm trust, percentage | 1% | ||||
Entergy Louisiana [Member] | Entergy Finance Company [Member] | Restoration Law Trust I [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | $ 3,000,000 | 3,200,000 | |||
Members' Equity Attributable to Noncontrolling Interest | 30,500 | 31,700 | |||
Members' Equity Attributable to Noncontrolling Interest | 30,500 | $ 31,700 | |||
Entergy Louisiana [Member] | Entergy Finance Company [Member] | Restoration Law Trust II [Member] | |||||
Variable Interest Entities (Textual) [Abstract] | |||||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | 1,500,000 | ||||
Members' Equity Attributable to Noncontrolling Interest | 14,600 | ||||
Members' Equity Attributable to Noncontrolling Interest | $ 14,600 |
Transactions With Affiliates Tr
Transactions With Affiliates Transactions with Affiliates (Narrative) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Related Party Transaction [Line Items] | |||
Costs and Expenses | $ 9,529,437 | $ 11,713,462 | $ 9,897,270 |
Transactions With Affiliates (D
Transactions With Affiliates (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Investment Income, Net | $ 162,726 | $ (75,581) | $ 430,466 |
Costs and Expenses | 9,529,437 | 11,713,462 | 9,897,270 |
Revenue from Contract with Customer, Excluding Assessed Tax | 12,147,412 | 13,764,237 | 11,742,896 |
Entergy Arkansas [Member] | |||
Investment Income, Net | 25,024 | 19,554 | 76,953 |
Costs and Expenses | 2,191,189 | 2,165,546 | 1,901,152 |
Revenue from Contract with Customer, Excluding Assessed Tax | 2,646,396 | 2,673,194 | 2,338,590 |
Entergy Arkansas [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 700 | 100 | 0 |
Costs and Expenses | 585,800 | 617,400 | 559,700 |
Revenue from Contract with Customer, Excluding Assessed Tax | 125,200 | 127,500 | 109,800 |
Entergy Louisiana [Member] | |||
Investment Income, Net | 90,316 | (69,144) | 154,606 |
Costs and Expenses | 3,984,619 | 5,436,579 | 4,141,668 |
Revenue from Contract with Customer, Excluding Assessed Tax | 5,147,770 | 6,338,768 | 5,068,448 |
Entergy Louisiana [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 303,200 | 186,100 | 127,600 |
Costs and Expenses | 719,800 | 770,200 | 755,200 |
Revenue from Contract with Customer, Excluding Assessed Tax | 317,600 | 354,000 | 289,900 |
Entergy Mississippi [Member] | |||
Investment Income, Net | 2,275 | 508 | 53 |
Costs and Expenses | 1,467,418 | 1,311,957 | 1,121,844 |
Revenue from Contract with Customer, Excluding Assessed Tax | 1,802,533 | 1,624,234 | 1,406,346 |
Entergy Mississippi [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 200 | 100 | 0 |
Costs and Expenses | 345,200 | 356,100 | 299,800 |
Revenue from Contract with Customer, Excluding Assessed Tax | 1,000 | 1,000 | 1,400 |
Entergy New Orleans [Member] | |||
Investment Income, Net | 7,154 | 742 | 48 |
Costs and Expenses | 772,069 | 876,207 | 704,189 |
Revenue from Contract with Customer, Excluding Assessed Tax | 843,933 | 997,333 | 768,852 |
Entergy New Orleans [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 1,000 | 100 | 0 |
Costs and Expenses | 302,500 | 341,700 | 287,800 |
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy Texas [Member] | |||
Investment Income, Net | 11,116 | 4,141 | 837 |
Costs and Expenses | 1,598,906 | 1,855,146 | 1,575,804 |
Revenue from Contract with Customer, Excluding Assessed Tax | 2,028,586 | 2,288,905 | 1,902,511 |
Entergy Texas [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 1,800 | 300 | 0 |
Costs and Expenses | 316,800 | 321,400 | 275,000 |
Revenue from Contract with Customer, Excluding Assessed Tax | 700 | 18,900 | 64,300 |
System Energy [Member] | |||
Investment Income, Net | 13,131 | 5,096 | 82,744 |
Costs and Expenses | 410,698 | 985,969 | 498,606 |
System Energy [Member] | Affiliated Entity [Member] | |||
Investment Income, Net | 600 | 300 | 0 |
Costs and Expenses | 179,000 | 215,000 | 190,800 |
Revenue from Contract with Customer, Excluding Assessed Tax | $ 588,400 | $ 658,800 | $ 545,600 |
Revenue Recognition Revenue R_3
Revenue Recognition Revenue Recognition (Narrative) (Details) $ in Millions | 5 Months Ended | 12 Months Ended | 29 Months Ended | 180 Months Ended | 185 Months Ended | ||
May 31, 2022 $ / MWh | Dec. 31, 2023 USD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2021 USD ($) | May 31, 2022 $ / MWh | Dec. 31, 2021 $ / MWh | May 31, 2022 $ / MWh | |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | $ 38.7 | $ 40.6 | |||||
COVID-19 Pandemic [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | (6.4) | ||||||
System Energy [Member] | |||||||
Percent Interest in Grand Gulf | 90% | ||||||
Entergy Louisiana [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | $ 13.9 | 10.7 | |||||
Entergy Louisiana [Member] | COVID-19 Pandemic [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | (8.5) | ||||||
Entergy Mississippi [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 7.3 | 3.2 | |||||
Entergy Texas [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 4.7 | 4.1 | |||||
Entergy Texas [Member] | COVID-19 Pandemic [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | (1.3) | ||||||
Entergy New Orleans [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 3.4 | 7.7 | |||||
Entergy New Orleans [Member] | COVID-19 Pandemic [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | (3) | ||||||
Entergy Arkansas [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | $ 9.4 | 14.9 | |||||
Entergy Arkansas [Member] | COVID-19 Pandemic [Member] | |||||||
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 6.4 | ||||||
Corporate and Other [Member] | Palisades [Member] | |||||||
Average Price Under PPA | $ / MWh | 51 | ||||||
Amortization of Intangible Assets | $ 5 | $ 12 | |||||
Contract price under purchase power agreement | $ / MWh | 61.50 | 24.14 | 43.50 |
Revenue Recognition Revenue R_4
Revenue Recognition Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Revenue from Contract with Customer, Excluding Assessed Tax | $ 12,147,412 | $ 13,764,237 | $ 11,742,896 |
Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 11,842,454 | 13,186,845 | 10,873,995 |
Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 180,490 | 233,920 | 170,610 |
Other [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 124,468 | 343,472 | 698,291 |
Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 4,552,804 | 4,640,039 | 3,981,846 |
Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,997,888 | 3,087,675 | 2,610,207 |
Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 3,170,090 | 3,716,058 | 2,942,370 |
Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 270,640 | 286,605 | 245,685 |
Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 366,348 | 858,743 | 601,895 |
Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 352,056 | 481,256 | 375,312 |
Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 11,709,826 | 13,070,376 | 10,757,315 |
Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 132,628 | 116,469 | 116,680 |
Non-Customer [Member] | Other [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 124,468 | 343,472 | 698,291 |
Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 10,991,422 | 11,730,377 | 9,780,108 |
Entergy Arkansas [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,646,396 | 2,673,194 | 2,338,590 |
Entergy Arkansas [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,646,396 | 2,673,194 | 2,338,590 |
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 996,760 | 946,719 | 882,773 |
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 584,304 | 530,512 | 480,401 |
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 635,472 | 559,147 | 496,661 |
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 20,409 | 20,186 | 19,112 |
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 269,648 | 443,685 | 311,791 |
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 121,425 | 159,178 | 130,443 |
Entergy Arkansas [Member] | Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,628,018 | 2,659,427 | 2,321,181 |
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 18,378 | 13,767 | 17,409 |
Entergy Arkansas [Member] | Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,236,945 | 2,056,564 | 1,878,947 |
Entergy Louisiana [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 5,147,770 | 6,338,768 | 5,068,448 |
Entergy Louisiana [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 5,073,239 | 6,246,933 | 4,994,459 |
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 74,531 | 91,835 | 73,989 |
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,576,129 | 1,775,552 | 1,484,612 |
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,104,509 | 1,274,665 | 1,055,825 |
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,720,298 | 2,275,978 | 1,771,311 |
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 83,736 | 94,910 | 82,503 |
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 357,900 | 555,640 | 391,424 |
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 151,252 | 204,878 | 148,304 |
Entergy Louisiana [Member] | Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 4,993,824 | 6,181,623 | 4,933,979 |
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 79,415 | 65,310 | 60,480 |
Entergy Louisiana [Member] | Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 4,484,672 | 5,421,105 | 4,394,251 |
Entergy Mississippi [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,802,533 | 1,624,234 | 1,406,346 |
Entergy Mississippi [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,802,533 | 1,624,234 | 1,406,346 |
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 748,428 | 651,455 | 578,258 |
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 604,343 | 508,996 | 439,950 |
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 217,916 | 182,270 | 150,698 |
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 60,477 | 52,861 | 46,248 |
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 104,058 | 167,867 | 124,632 |
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 49,752 | 51,554 | 58,357 |
Entergy Mississippi [Member] | Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,784,974 | 1,615,003 | 1,398,143 |
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 17,559 | 9,231 | 8,203 |
Entergy Mississippi [Member] | Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,631,164 | 1,395,582 | 1,215,154 |
Entergy New Orleans [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 843,933 | 997,333 | 768,852 |
Entergy New Orleans [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 737,974 | 855,248 | 672,231 |
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 105,959 | 142,085 | 96,621 |
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 317,188 | 335,471 | 269,891 |
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 235,193 | 256,963 | 208,104 |
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 31,831 | 36,970 | 30,751 |
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 77,152 | 87,514 | 71,584 |
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 63,360 | 120,851 | 88,349 |
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | (992) | 13,637 | 1,813 |
Entergy New Orleans [Member] | Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 723,732 | 851,406 | 670,492 |
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 14,242 | 3,842 | 1,739 |
Entergy New Orleans [Member] | Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 661,364 | 716,918 | 580,330 |
Entergy Texas [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,028,586 | 2,288,905 | 1,902,511 |
Entergy Texas [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,028,586 | 2,288,905 | 1,902,511 |
Entergy Texas [Member] | Natural Gas, US Regulated [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 |
Entergy Texas [Member] | Residential [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 914,299 | 930,842 | 766,312 |
Entergy Texas [Member] | Commercial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 469,539 | 516,539 | 425,927 |
Entergy Texas [Member] | Industrial [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 564,573 | 661,693 | 492,949 |
Entergy Texas [Member] | Governmental [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 28,866 | 31,134 | 26,238 |
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 10,497 | 66,782 | 145,719 |
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 35,988 | 57,379 | 41,805 |
Entergy Texas [Member] | Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,023,762 | 2,264,369 | 1,898,950 |
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 4,824 | 24,536 | 3,561 |
Entergy Texas [Member] | Billed Retail [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,977,277 | 2,140,208 | 1,711,426 |
System Energy [Member] | Electricity [Member] | |||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 586,603 | $ 658,812 | $ 570,848 |
Revenue Recognition (Allowance
Revenue Recognition (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
Allowance for Credit Loss, Receivable, Other, Current | $ 25.9 | $ 30.9 | $ 68.6 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 38.7 | 40.6 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (83.1) | (112.5) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | 39.4 | 34.2 | |
Entergy Arkansas [Member] | |||
Allowance for Credit Loss, Receivable, Other, Current | 7.2 | 6.5 | 13.1 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 9.4 | 14.9 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (20.6) | (31.2) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | 11.9 | 9.7 | |
Entergy Louisiana [Member] | |||
Allowance for Credit Loss, Receivable, Other, Current | 6.1 | 7.6 | 29.2 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 13.9 | 10.7 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (31.3) | (45.1) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | 15.9 | 12.8 | |
Entergy New Orleans [Member] | |||
Allowance for Credit Loss, Receivable, Other, Current | 7.8 | 11.9 | 13.3 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 3.4 | 7.7 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (10.7) | (13.5) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | 3.2 | 4.4 | |
Entergy Mississippi [Member] | |||
Allowance for Credit Loss, Receivable, Other, Current | 3.3 | 2.5 | 7.2 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 7.3 | 3.2 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (10.4) | (12.1) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | 3.9 | 4.2 | |
Entergy Texas [Member] | |||
Allowance for Credit Loss, Receivable, Other, Current | 1.5 | 2.4 | $ 5.8 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 4.7 | 4.1 | |
Accounts Receivable, Allowance for Credit Loss, Writeoff | (10.1) | (10.6) | |
Accounts Receivable, Allowance for Credit Loss, Recovery | $ 4.5 | $ 3.1 |
Schedule II - Valuation And Q_2
Schedule II - Valuation And Qualifying Accounts (Details) - Allowance for Doubtful Accounts Receivable [Member] - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2023 | Dec. 31, 2022 | Dec. 31, 2021 | |
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | $ 30,856 | $ 68,608 | $ 117,794 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 38,508 | 40,307 | 57,517 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 43,459 | 78,059 | 106,703 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | 25,905 | 30,856 | 68,608 |
Entergy Arkansas [Member] | |||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | 6,528 | 13,072 | 18,334 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 9,428 | 14,947 | 30,433 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 8,774 | 21,491 | 35,695 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | 7,182 | 6,528 | 13,072 |
Entergy New Orleans [Member] | |||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | 11,909 | 13,282 | 17,430 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 3,350 | 7,691 | 6,850 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 7,489 | 9,064 | 10,998 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | 7,770 | 11,909 | 13,282 |
Entergy Mississippi [Member] | |||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | 2,472 | 7,209 | 19,527 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 7,275 | 3,052 | 850 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 6,435 | 7,789 | 13,168 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | 3,312 | 2,472 | 7,209 |
Entergy Louisiana [Member] | |||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | 7,595 | 29,231 | 45,693 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 13,876 | 10,574 | 17,219 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 15,315 | 32,210 | 33,681 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | 6,156 | 7,595 | 29,231 |
Entergy Texas [Member] | |||
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward] | |||
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Beginning Balance | 2,352 | 5,814 | 16,810 |
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts | 4,579 | 4,042 | 2,166 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction | 5,447 | 7,504 | 13,162 |
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount, Ending Balance | $ 1,484 | $ 2,352 | $ 5,814 |
Uncategorized Items - etr-20231
Label | Element | Value |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | $ 1,759,099,000 |
Entergy Texas [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 248,596,000 |
System Energy [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 242,469,000 |
Entergy New Orleans [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 26,000 |
Entergy Louisiana [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 728,020,000 |
Entergy Mississippi [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 18,000 |
Entergy Arkansas [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | $ 192,128,000 |