Document and Entity Information
Document and Entity Information - shares | 6 Months Ended | |
Jun. 30, 2024 | Jul. 31, 2024 | |
Entity Registrant Name | ENTERGY CORPORATION | |
City Area Code | 504 | |
Local Phone Number | 576-4000 | |
Entity Tax Identification Number | 72-1229752 | |
Entity File Number | 1-11299 | |
Entity Central Index Key | 0000065984 | |
Document Type | 10-Q | |
Document Period End Date | Jun. 30, 2024 | |
Amendment Flag | false | |
Document Fiscal Year Focus | 2024 | |
Document Fiscal Period Focus | Q2 | |
Current Fiscal Year End Date | --12-31 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Large Accelerated Filer | |
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 | |
Entity Common Stock, Shares Outstanding | 213,830,846 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Document Quarterly Report | true | |
Document Transition Report | false | |
NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | ETR | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Common Stock, $0.01 Par Value | |
NYSE CHICAGO, INC. [Member] | ||
Trading Symbol | ETR | |
Security Exchange Name | CHX | |
Title of 12(b) Security | Common Stock, $0.01 Par Value | |
Entergy Arkansas [Member] | ||
Entity Registrant Name | ENTERGY ARKANSAS, LLC | |
City Area Code | 501 | |
Local Phone Number | 377-4000 | |
Entity Tax Identification Number | 83-1918668 | |
Entity File Number | 1-10764 | |
Entity Central Index Key | 0000007323 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Entergy Louisiana [Member] | ||
Entity Registrant Name | ENTERGY LOUISIANA, LLC | |
City Area Code | 504 | |
Local Phone Number | 576-4000 | |
Entity Tax Identification Number | 47-4469646 | |
Entity File Number | 1-32718 | |
Entity Central Index Key | 0001348952 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Entergy Mississippi [Member] | ||
Entity Registrant Name | ENTERGY MISSISSIPPI, LLC | |
City Area Code | 601 | |
Local Phone Number | 368-5000 | |
Entity Tax Identification Number | 83-1950019 | |
Entity File Number | 1-31508 | |
Entity Central Index Key | 0000066901 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Entergy New Orleans [Member] | ||
Entity Registrant Name | ENTERGY NEW ORLEANS, LLC | |
City Area Code | 504 | |
Local Phone Number | 670-3702 | |
Entity Tax Identification Number | 82-2212934 | |
Entity File Number | 1-35747 | |
Entity Central Index Key | 0000071508 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Entergy Texas [Member] | ||
Entity Registrant Name | ENTERGY TEXAS, INC. | |
City Area Code | 409 | |
Local Phone Number | 981-2000 | |
Entity Tax Identification Number | 61-1435798 | |
Entity File Number | 1-34360 | |
Entity Central Index Key | 0001427437 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
System Energy [Member] | ||
Entity Registrant Name | SYSTEM ENERGY RESOURCES, INC. | |
City Area Code | 601 | |
Local Phone Number | 368-5000 | |
Entity Tax Identification Number | 72-0752777 | |
Entity File Number | 1-09067 | |
Entity Central Index Key | 0000202584 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Non-accelerated Filer | |
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 | |
Entity Emerging Growth Company | false | |
Entity Small Business | false | |
Entity Shell Company | false | |
Entity Interactive Data Current | Yes | |
Mortgage Bonds5.50% Series Due April 2066 [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | ENO | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Mortgage Bonds, 5.50% Series due April 2066 | |
Mortgage Bonds 5.0% Series Due December 2052 [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | ENJ | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Mortgage Bonds, 5.0% Series due December 2052 | |
Mortgage Bonds 4.90% Series Due October 2066 [Member] | Entergy Mississippi [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | EMP | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Mortgage Bonds, 4.90% Series due October 2066 | |
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | EAI | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Mortgage Bonds, 4.875% Series due September 2066 | |
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | ELC | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | Mortgage Bonds, 4.875% Series due September 2066 | |
5.375% Series A Preferred Stock, Cumulative, No Par Value [Member] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | ||
Trading Symbol | ETI/PR | |
Security Exchange Name | NYSE | |
Title of 12(b) Security | 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share) |
Consolidated Statements Of Inco
Consolidated Statements Of Income - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 2,953,620 | $ 2,846,026 | $ 5,748,248 | $ 5,827,085 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 522,550 | 583,717 | 1,139,166 | 1,482,100 |
Utilities Operating Expense, Purchased Power | 200,705 | 206,536 | 428,847 | 444,823 |
Nuclear refueling outage expenses | 38,277 | 34,785 | 76,540 | 72,018 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 701,775 | 659,894 | 1,388,806 | 1,291,421 |
Asset Impairment Charges | 0 | 0 | 131,775 | 0 |
Decommissioning | 54,193 | 51,152 | 107,574 | 101,644 |
Taxes, Other | 187,520 | 183,578 | 379,949 | 369,015 |
Other Depreciation and Amortization | 505,363 | 468,938 | 1,005,024 | 922,855 |
Other Regulatory Charges (Credits) - Net | 125,607 | (98,501) | 234,954 | (74,827) |
Costs and Expenses, Total | 2,335,990 | 2,090,099 | 4,892,635 | 4,609,049 |
OPERATING INCOME | 617,630 | 755,927 | 855,613 | 1,218,036 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 29,275 | 24,867 | 56,070 | 48,013 |
Investment Income, Net | 70,587 | 45,428 | 221,283 | 93,687 |
Miscellaneous - net | (342,549) | (48,544) | (393,294) | (102,997) |
TOTAL | (242,687) | 21,751 | (115,941) | 38,703 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 301,263 | 261,349 | 579,006 | 516,678 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 11,686 | 10,481 | 22,229 | 20,072 |
TOTAL | 289,577 | 250,868 | 556,777 | 496,606 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 85,366 | 526,810 | 182,895 | 760,133 |
Income taxes | 33,634 | 134,796 | 54,627 | 55,821 |
Consolidated net income | 51,732 | 392,014 | 128,268 | 704,312 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | $ 2,810 | $ 770 | $ 4,065 | $ 2,133 |
Earnings per average common share: | ||||
Earnings Per Share, Basic | $ 0.23 | $ 1.85 | $ 0.58 | $ 3.32 |
Earnings Per Share, Diluted | $ 0.23 | $ 1.84 | $ 0.58 | $ 3.31 |
Weighted Average Number of Shares Outstanding, Basic | 213,617,110 | 211,449,211 | 213,380,414 | 211,400,230 |
Weighted Average Number of Shares Outstanding, Diluted | 214,376,721 | 212,201,529 | 214,155,768 | 212,173,254 |
Net Income (Loss) Available to Common Stockholders, Basic, Total | $ 48,922 | $ 391,244 | $ 124,203 | $ 702,179 |
Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,906,047 | 2,785,244 | 5,612,553 | 5,668,654 |
Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 35,357 | 33,503 | 101,024 | 98,084 |
Other [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 12,216 | 27,279 | 34,671 | 60,347 |
Entergy Mississippi [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 442,894 | 445,130 | 857,750 | 857,558 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 63,977 | 140,530 | 181,827 | 301,815 |
Utilities Operating Expense, Purchased Power | 66,847 | 59,140 | 134,502 | 122,954 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 67,700 | 68,600 | 138,906 | 138,418 |
Taxes, Other | 37,496 | 35,301 | 75,806 | 71,035 |
Other Depreciation and Amortization | 67,131 | 65,346 | 133,048 | 129,375 |
Other Regulatory Charges (Credits) - Net | 9,873 | (25,947) | 3,382 | (58,790) |
Costs and Expenses, Total | 313,024 | 342,970 | 667,471 | 704,807 |
OPERATING INCOME | 129,870 | 102,160 | 190,279 | 152,751 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 3,094 | 2,169 | 5,012 | 4,053 |
Investment Income, Net | 948 | 1,319 | 1,141 | 1,783 |
Miscellaneous - net | (1,772) | (3,438) | (3,393) | (5,521) |
TOTAL | 2,270 | 50 | 2,760 | 315 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 28,499 | 25,433 | 54,896 | 49,377 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 1,204 | 902 | 1,951 | 1,685 |
TOTAL | 27,295 | 24,531 | 52,945 | 47,692 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 104,845 | 77,679 | 140,094 | 105,374 |
Income taxes | 25,280 | 19,414 | 33,097 | 26,169 |
Consolidated net income | 79,565 | 58,265 | 106,997 | 79,205 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (1,733) | (3,623) | (4,035) | (5,764) |
Earnings per average common share: | ||||
Net Income (Loss) Available to Common Stockholders, Basic, Total | 81,298 | 61,888 | 111,032 | 84,969 |
Entergy Mississippi [Member] | Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 442,894 | 445,130 | 857,750 | 857,558 |
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
Entergy Arkansas [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 608,798 | 616,347 | 1,230,843 | 1,199,096 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 52,756 | 102,350 | 159,195 | 215,859 |
Utilities Operating Expense, Purchased Power | 55,602 | 57,648 | 107,922 | 122,399 |
Nuclear refueling outage expenses | 14,101 | 15,504 | 28,189 | 30,845 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 174,835 | 178,044 | 352,876 | 334,863 |
Asset Impairment Charges | 0 | 0 | 131,775 | 0 |
Decommissioning | 22,832 | 21,667 | 45,479 | 43,017 |
Taxes, Other | 34,390 | 34,743 | 70,614 | 67,094 |
Other Depreciation and Amortization | 103,966 | 99,707 | 206,957 | 196,148 |
Other Regulatory Charges (Credits) - Net | (20,934) | (19,185) | 27,685 | (40,029) |
Costs and Expenses, Total | 437,548 | 490,478 | 1,130,692 | 970,196 |
OPERATING INCOME | 171,250 | 125,869 | 100,151 | 228,900 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 5,862 | 5,400 | 11,394 | 10,243 |
Investment Income, Net | 5,181 | 5,727 | 77,941 | 13,206 |
Miscellaneous - net | (2,799) | (6,239) | (6,380) | (8,340) |
TOTAL | 8,244 | 4,888 | 82,955 | 15,109 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 54,879 | 46,038 | 104,144 | 91,405 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 2,864 | 2,169 | 5,563 | 4,114 |
TOTAL | 52,015 | 43,869 | 98,581 | 87,291 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 127,479 | 86,888 | 84,525 | 156,718 |
Income taxes | 32,120 | 19,940 | 21,446 | 30,374 |
Consolidated net income | 95,359 | 66,948 | 63,079 | 126,344 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (825) | (1,006) | (2,643) | (2,635) |
Earnings per average common share: | ||||
Net Income (Loss) Available to Common Stockholders, Basic, Total | 96,184 | 67,954 | 65,722 | 128,979 |
Entergy Arkansas [Member] | Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 608,798 | 616,347 | 1,230,843 | 1,199,096 |
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
Entergy Louisiana [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,276,124 | 1,205,612 | 2,478,564 | 2,550,820 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 246,571 | 230,365 | 486,658 | 605,635 |
Utilities Operating Expense, Purchased Power | 166,868 | 133,376 | 367,148 | 328,310 |
Nuclear refueling outage expenses | 20,041 | 12,588 | 37,554 | 27,861 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 275,168 | 249,717 | 536,147 | 496,088 |
Decommissioning | 20,061 | 18,820 | 39,725 | 37,406 |
Taxes, Other | 70,629 | 61,663 | 140,468 | 125,618 |
Other Depreciation and Amortization | 190,861 | 181,247 | 380,405 | 357,342 |
Other Regulatory Charges (Credits) - Net | 120,298 | (24,767) | 111,944 | 49,229 |
Costs and Expenses, Total | 1,110,497 | 863,009 | 2,100,049 | 2,027,489 |
OPERATING INCOME | 165,627 | 342,603 | 378,515 | 523,331 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 7,522 | 8,654 | 14,807 | 17,715 |
Investment Income, Net | 15,229 | 31,880 | 78,192 | 60,723 |
Miscellaneous - net | (20,646) | (42,583) | (67,821) | (90,668) |
TOTAL | 82,180 | 79,828 | 185,657 | 125,073 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 98,536 | 94,931 | 195,731 | 192,102 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 2,593 | 4,321 | 5,070 | 8,714 |
TOTAL | 95,943 | 90,610 | 190,661 | 183,388 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 151,864 | 331,821 | 373,511 | 465,016 |
Income taxes | 20,750 | 68,561 | 59,674 | (42,268) |
Consolidated net income | 131,114 | 263,260 | 313,837 | 507,284 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 788 | 819 | 1,583 | 1,373 |
Earnings per average common share: | ||||
Net Income (Loss) Available to Common Stockholders, Basic, Total | 130,326 | 262,441 | 312,254 | 505,911 |
Entergy Louisiana [Member] | Affiliated Entity [Member] | ||||
OTHER INCOME (DEDUCTIONS) | ||||
Investment Income, Net | 80,075 | 81,877 | 160,479 | 137,303 |
Entergy Louisiana [Member] | Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,261,444 | 1,191,909 | 2,434,237 | 2,511,661 |
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 14,680 | 13,703 | 44,327 | 39,159 |
Entergy New Orleans [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 199,341 | 188,016 | 392,302 | 396,836 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 18,314 | 18,974 | 49,139 | 70,998 |
Utilities Operating Expense, Purchased Power | 64,318 | 65,929 | 124,700 | 132,549 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 41,720 | 38,961 | 85,052 | 72,188 |
Taxes, Other | 14,187 | 14,480 | 29,609 | 30,904 |
Other Depreciation and Amortization | 21,130 | 20,064 | 42,044 | 39,639 |
Other Regulatory Charges (Credits) - Net | 1,659 | 2,288 | 83,179 | 1,187 |
Costs and Expenses, Total | 161,328 | 160,696 | 413,723 | 347,465 |
OPERATING INCOME | 38,013 | 27,320 | (21,421) | 49,371 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 511 | 280 | 889 | 730 |
Investment Income, Net | 316 | 2,400 | 457 | 4,451 |
Miscellaneous - net | 381 | (517) | 352 | (744) |
TOTAL | 1,208 | 2,163 | 1,698 | 4,437 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 10,810 | 10,003 | 20,336 | 19,622 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 214 | 136 | 371 | 355 |
TOTAL | 10,596 | 9,867 | 19,965 | 19,267 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 28,625 | 19,616 | (39,688) | 34,541 |
Income taxes | 7,492 | 5,759 | (11,841) | 10,542 |
Consolidated net income | 21,133 | 13,857 | (27,847) | 23,999 |
Entergy New Orleans [Member] | Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 178,664 | 168,216 | 335,605 | 337,911 |
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 20,677 | 19,800 | 56,697 | 58,925 |
Entergy Texas [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 519,077 | 464,430 | 963,568 | 971,936 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 115,520 | 63,526 | 211,657 | 231,056 |
Utilities Operating Expense, Purchased Power | 88,713 | 112,883 | 183,056 | 220,641 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 83,176 | 63,071 | 161,136 | 127,501 |
Taxes, Other | 22,979 | 28,717 | 47,546 | 56,713 |
Other Depreciation and Amortization | 90,824 | 66,009 | 180,329 | 125,400 |
Other Regulatory Charges (Credits) - Net | (12,477) | 1,526 | (13,452) | 12,450 |
Costs and Expenses, Total | 388,735 | 335,732 | 770,272 | 773,761 |
OPERATING INCOME | 130,342 | 128,698 | 193,296 | 198,175 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 10,834 | 6,760 | 20,082 | 11,849 |
Investment Income, Net | 2,791 | 846 | 6,695 | 2,263 |
Miscellaneous - net | (3,186) | (1,941) | (5,498) | (1,502) |
TOTAL | 10,439 | 5,665 | 21,279 | 12,610 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 34,483 | 26,847 | 66,449 | 53,809 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 4,219 | 2,517 | 7,821 | 4,413 |
TOTAL | 30,264 | 24,330 | 58,628 | 49,396 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 110,517 | 110,033 | 155,947 | 161,389 |
Income taxes | 20,295 | 21,576 | 28,981 | 31,259 |
Consolidated net income | 90,222 | 88,457 | 126,966 | 130,130 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 518 | 518 | 1,036 | 1,036 |
Earnings per average common share: | ||||
Net Income (Loss) Available to Common Stockholders, Basic, Total | 89,704 | 87,939 | 125,930 | 129,094 |
Entergy Texas [Member] | Electricity [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 519,077 | 464,430 | 963,568 | 971,936 |
Entergy Texas [Member] | Natural Gas, US Regulated [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
System Energy [Member] | ||||
Revenues [Abstract] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 145,934 | 138,384 | 298,554 | 309,956 |
Operation and Maintenance: | ||||
Fuel, fuel-related expenses, and gas purchased for resale | 17,120 | 18,783 | 30,237 | 37,630 |
Nuclear refueling outage expenses | 4,136 | 6,692 | 10,797 | 13,311 |
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | 45,746 | 46,986 | 97,169 | 97,186 |
Decommissioning | 10,815 | 10,391 | 21,522 | 20,678 |
Taxes, Other | 6,892 | 7,728 | 14,101 | 15,010 |
Other Depreciation and Amortization | 30,443 | 35,303 | 60,121 | 72,440 |
Other Regulatory Charges (Credits) - Net | 27,188 | (32,415) | 22,215 | (38,874) |
Costs and Expenses, Total | 142,340 | 93,468 | 256,162 | 217,381 |
OPERATING INCOME | 3,594 | 44,916 | 42,392 | 92,575 |
OTHER INCOME (DEDUCTIONS) | ||||
Allowance for equity funds used during construction | 1,451 | 1,605 | 3,885 | 3,423 |
Investment Income, Net | 38,967 | 1,638 | 46,940 | 7,402 |
Miscellaneous - net | (165) | (1,613) | 72 | (10,691) |
TOTAL | 40,253 | 1,630 | 50,897 | 134 |
INTEREST EXPENSE | ||||
Interest Expense, Debt | 12,072 | 13,635 | 23,243 | 24,126 |
Public Utilities, Allowance for Funds Used During Construction, Additions | 594 | 436 | 1,453 | 791 |
TOTAL | 11,478 | 13,199 | 21,790 | 23,335 |
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total | 32,369 | 33,347 | 71,499 | 69,374 |
Income taxes | 7,521 | 7,588 | 15,533 | 16,070 |
Consolidated net income | 24,848 | 25,759 | 55,966 | 53,304 |
Earnings per average common share: | ||||
Net Income (Loss) Available to Common Stockholders, Basic, Total | $ 24,848 | $ 25,759 | $ 55,966 | $ 53,304 |
Consolidated Statements Of Cash
Consolidated Statements Of Cash Flows - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Jun. 30, 2023 | |
OPERATING ACTIVITIES | ||
Consolidated net income | $ 128,268 | $ 704,312 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 1,206,492 | 1,116,843 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 15,998 | 43,502 |
Asset Impairment Charges | 131,775 | 0 |
Pension Expense (Reversal of Expense), Noncash | 316,738 | 0 |
Changes in working capital: | ||
Receivables | (187,554) | 65,259 |
Fuel inventory | 18,324 | (43,493) |
Accounts payable | (149,554) | (267,820) |
Taxes accrued | 16,546 | (25,080) |
Interest accrued | 23,560 | 6,807 |
Deferred fuel costs | 134,953 | 563,610 |
Other working capital accounts | (120,277) | (148,738) |
Changes in provisions for estimated losses | 4,630 | (16,564) |
Changes in regulatory assets | 260,722 | 391,188 |
Increase (Decrease) in Regulatory Liabilities | 380,394 | 308,058 |
Effect of securitization on regulatory asset | 0 | (491,150) |
Changes in pension and other postretirement funded status | (131,539) | (128,379) |
Other Operating Activities, Cash Flow Statement | (503,020) | (252,383) |
Net cash flow provided by operating activities | 1,546,456 | 1,825,972 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (2,124,279) | (2,311,465) |
Allowance for equity funds used during construction | 56,070 | 48,013 |
Proceeds from Sale of Productive Assets | 0 | 11,000 |
Nuclear fuel purchases | (161,483) | (134,698) |
Payments for Nuclear Fuel | (161,483) | (134,698) |
Proceeds from Insurance Settlement, Investing Activities | 0 | 6,184 |
Payments to storm reserve escrow accounts | (9,595) | (9,080) |
Decrease (increase) in other investments | (9,689) | 262 |
Proceeds from nuclear decommissioning trust fund sales | 1,201,162 | 435,903 |
Investment in nuclear decommissioning trust funds | (1,250,039) | (486,853) |
Changes in securitization account | 3,976 | 7,803 |
Net cash flow used in investing activities | (2,466,491) | (2,445,431) |
Payments for (Proceeds from) Other Investing Activities | 9,689 | (262) |
Litigation proceeds for reimbursement of spent nuclear fuel storage costs | 0 | 17,933 |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (5,068,266) | (2,489,886) |
Proceeds from Sale of Treasury Stock | 45,982 | 4,078 |
Retirement of long-term debt | (2,379,903) | (2,273,773) |
Proceeds received by storm trusts related to securitization | 0 | 1,457,676 |
Dividends paid: | ||
Common stock | (482,255) | (452,442) |
Payments of Ordinary Dividends, Preferred Stock and Preference Stock | 9,159 | 9,159 |
Proceeds from (Payments for) Other Financing Activities | 105,540 | 66,898 |
Net cash flow provided by financing activities | 2,142,651 | 1,589,637 |
Proceeds from Noncontrolling Interests | 0 | 25,708 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 1,222,616 | 970,178 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 1,355,164 | 1,194,342 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 532,742 | 490,201 |
Income taxes | 7,822 | 31,231 |
Proceeds from (Repayments of) Short-Term Debt | (205,820) | 280,765 |
Payments to Acquire Productive Assets | (172,614) | (30,433) |
Capital Expenditures Incurred but Not yet Paid | 537,463 | 535,714 |
Entergy Arkansas [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | 63,079 | 126,344 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 287,564 | 270,098 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 41,130 | 33,572 |
Asset Impairment Charges | 131,775 | 0 |
Changes in working capital: | ||
Receivables | 67,067 | 21,444 |
Fuel inventory | 10,890 | (6,830) |
Accounts payable | 26,093 | (43,953) |
Taxes accrued | (15,496) | (4,315) |
Interest accrued | 4,647 | 10,421 |
Deferred fuel costs | 2,317 | 123,264 |
Other working capital accounts | (13,243) | (30,581) |
Changes in provisions for estimated losses | 5,725 | (26,606) |
Changes in regulatory assets | 179,719 | (51,960) |
Increase (Decrease) in Regulatory Liabilities | 71,529 | 97,349 |
Changes in pension and other postretirement funded status | (27,588) | (18,948) |
Other Operating Activities, Cash Flow Statement | (310,500) | (91,600) |
Net cash flow provided by operating activities | 524,708 | 407,699 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (394,973) | (524,723) |
Allowance for equity funds used during construction | 11,394 | 10,243 |
Nuclear fuel purchases | (65,010) | (73,912) |
Payments for Nuclear Fuel | (65,010) | (73,912) |
Proceeds from Nuclear Fuel | 33,213 | 17,614 |
Change in money pool receivable - net | (130,602) | 0 |
Decrease (increase) in other investments | 30 | 106 |
Proceeds from nuclear decommissioning trust fund sales | 412,931 | 54,469 |
Investment in nuclear decommissioning trust funds | (418,818) | (65,584) |
Net cash flow used in investing activities | (721,529) | (563,854) |
Payments for (Proceeds from) Other Investing Activities | (30) | (106) |
Litigation proceeds for reimbursement of spent nuclear fuel storage costs | 0 | 17,933 |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (970,030) | (661,923) |
Retirement of long-term debt | (555,411) | (394,810) |
Proceeds from Contributions from Parent | 695,000 | 0 |
Change in money pool payable - net | (145,385) | (28,468) |
Dividends paid: | ||
Common stock | 0 | (89,000) |
Proceeds from (Payments for) Other Financing Activities | 15,287 | 5,445 |
Net cash flow provided by financing activities | 979,521 | 155,090 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 782,700 | (1,065) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 786,332 | 4,213 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 49,597 | 79,716 |
Income taxes | 1,569 | 0 |
Payments to Acquire Productive Assets | (169,694) | 0 |
Capital Expenditures Incurred but Not yet Paid | 36,355 | 113,205 |
Entergy Louisiana [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | 313,837 | 507,284 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 453,888 | 423,535 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 146,540 | 185 |
Changes in working capital: | ||
Receivables | (161,001) | 67,807 |
Fuel inventory | 6,890 | (14,907) |
Accounts payable | (1,443) | (147,001) |
Taxes accrued | 27,677 | 48,015 |
Interest accrued | 14,163 | (5,396) |
Deferred fuel costs | 11,364 | 188,801 |
Other working capital accounts | (190,407) | (213,571) |
Changes in provisions for estimated losses | 9,519 | 3,909 |
Changes in regulatory assets | (9,005) | 448,144 |
Increase (Decrease) in Regulatory Liabilities | 286,036 | 217,746 |
Effect of securitization on regulatory asset | 0 | (491,150) |
Changes in pension and other postretirement funded status | (22,548) | (12,364) |
Other Operating Activities, Cash Flow Statement | (77,112) | (92,977) |
Net cash flow provided by operating activities | 808,398 | 928,060 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (685,206) | (889,118) |
Allowance for equity funds used during construction | 14,807 | 17,715 |
Nuclear fuel purchases | (52,992) | (88,403) |
Payments for Nuclear Fuel | (52,992) | (88,403) |
Proceeds from Nuclear Fuel | 38,822 | 16,733 |
Change in money pool receivable - net | (31,361) | (275,559) |
Proceeds from Insurance Settlement, Investing Activities | 0 | 6,184 |
Payments to storm reserve escrow accounts | (6,553) | (6,602) |
Payments to Acquire Interest in Subsidiaries and Affiliates | 0 | 1,457,676 |
Redemption of preferred membership interests of affiliate | 113,942 | 46,643 |
Decrease (increase) in other investments | 33 | 396 |
Proceeds from nuclear decommissioning trust fund sales | 333,149 | 229,972 |
Investment in nuclear decommissioning trust funds | (363,736) | (258,420) |
Net cash flow used in investing activities | (639,095) | (2,658,135) |
Payments for (Proceeds from) Other Investing Activities | (33) | (396) |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (1,825,954) | (833,484) |
Retirement of long-term debt | (1,061,918) | (851,617) |
Proceeds from Contributions from Parent | 0 | 1,457,676 |
Proceeds received by storm trusts related to securitization | 0 | 1,457,676 |
Change in money pool payable - net | (156,166) | (226,114) |
Dividends paid: | ||
Common stock | (664,100) | (160,250) |
Proceeds from (Payments for) Other Financing Activities | 69,936 | 19,633 |
Net cash flow provided by financing activities | 13,706 | 2,530,488 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 183,009 | 800,413 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 185,781 | 857,026 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 177,455 | 192,861 |
Income taxes | 58 | (6,037) |
Capital Expenditures Incurred but Not yet Paid | 81,177 | 138,522 |
Entergy Mississippi [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | 106,997 | 79,205 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 133,048 | 129,375 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 24,931 | 26,736 |
Changes in working capital: | ||
Receivables | (26,254) | (6,155) |
Fuel inventory | (2,331) | (5,919) |
Accounts payable | 475 | (32,930) |
Taxes accrued | (48,627) | (45,044) |
Interest accrued | (1,845) | (724) |
Deferred fuel costs | 41,104 | 149,189 |
Other working capital accounts | (18,367) | (25,035) |
Changes in provisions for estimated losses | (11,575) | 1,731 |
Changes in regulatory assets | 5,325 | (39,846) |
Increase (Decrease) in Regulatory Liabilities | (3,415) | (55,443) |
Changes in pension and other postretirement funded status | (8,968) | (8,261) |
Other Operating Activities, Cash Flow Statement | (5,194) | 6,669 |
Net cash flow provided by operating activities | 185,304 | 173,548 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (319,053) | (276,530) |
Allowance for equity funds used during construction | 5,012 | 4,053 |
Change in money pool receivable - net | 0 | 26,879 |
Decrease (increase) in other investments | (104) | (686) |
Net cash flow used in investing activities | (314,145) | (276,717) |
Payments for (Proceeds from) Other Investing Activities | 104 | 686 |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (396,105) | (396,861) |
Retirement of long-term debt | (200,000) | (400,000) |
Change in money pool payable - net | (33,414) | 104,624 |
Dividends paid: | ||
Common stock | (22,300) | (40,000) |
Proceeds from (Payments for) Other Financing Activities | (15,067) | 7,450 |
Net cash flow provided by financing activities | 125,324 | 94,643 |
Proceeds from Noncontrolling Interests | 0 | 25,708 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | (3,517) | (8,526) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 3,113 | 8,453 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 55,538 | 48,771 |
Income taxes | 2,356 | 0 |
Payments to Acquire Productive Assets | 0 | (30,433) |
Capital Expenditures Incurred but Not yet Paid | 22,334 | 66,818 |
Entergy New Orleans [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | (27,847) | 23,999 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 42,044 | 39,639 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | (19,560) | 10,247 |
Changes in working capital: | ||
Receivables | (111,913) | 23,357 |
Fuel inventory | 544 | 3,868 |
Accounts payable | (10,311) | (24,536) |
Taxes accrued | 7,345 | (657) |
Interest accrued | (1,220) | 194 |
Deferred fuel costs | (51) | 4,315 |
Other working capital accounts | (8,120) | (14,016) |
Changes in provisions for estimated losses | 2,473 | 3,550 |
Changes in regulatory assets | 11,073 | 2,930 |
Increase (Decrease) in Regulatory Liabilities | 167,529 | 30,722 |
Changes in pension and other postretirement funded status | (3,876) | (2,454) |
Other Operating Activities, Cash Flow Statement | (2,694) | (208) |
Net cash flow provided by operating activities | 45,416 | 100,950 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (72,409) | (88,480) |
Allowance for equity funds used during construction | 889 | 730 |
Change in money pool receivable - net | (1,110) | 101,767 |
Payments to storm reserve escrow accounts | (2,939) | (1,723) |
Decrease (increase) in other investments | 0 | 51 |
Changes in securitization account | 1,120 | 555 |
Net cash flow used in investing activities | (74,449) | 12,900 |
Payments for (Proceeds from) Other Investing Activities | 0 | (51) |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (149,075) | (14,641) |
Retirement of long-term debt | (91,245) | (6,073) |
Change in money pool payable - net | (21,651) | 0 |
Dividends paid: | ||
Proceeds from (Payments for) Other Financing Activities | (614) | (511) |
Net cash flow provided by financing activities | 35,565 | 23,057 |
Proceeds from Contribution in Aid of Construction | 0 | 15,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 6,532 | 136,907 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 6,558 | 141,371 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 20,159 | 18,719 |
Income taxes | 2,598 | 2 |
Capital Expenditures Incurred but Not yet Paid | 4,263 | 8,496 |
Entergy Texas [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | 126,966 | 130,130 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 180,329 | 125,400 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 21,112 | 23,480 |
Changes in working capital: | ||
Receivables | (64,108) | 12,534 |
Fuel inventory | 1,877 | (18,082) |
Accounts payable | 13,853 | (5,725) |
Taxes accrued | (21,155) | (45,549) |
Interest accrued | (561) | (604) |
Deferred fuel costs | 80,220 | 98,042 |
Other working capital accounts | (9,386) | 3,129 |
Changes in provisions for estimated losses | (1,384) | 455 |
Changes in regulatory assets | 40,197 | (19,688) |
Increase (Decrease) in Regulatory Liabilities | (26,028) | (9,929) |
Changes in pension and other postretirement funded status | (8,190) | (4,191) |
Other Operating Activities, Cash Flow Statement | (41,322) | 18,864 |
Net cash flow provided by operating activities | 292,420 | 308,266 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (522,890) | (448,550) |
Allowance for equity funds used during construction | 20,082 | 11,849 |
Proceeds from Sale of Productive Assets | 0 | 11,000 |
Change in money pool receivable - net | 296,670 | 98,569 |
Decrease (increase) in other investments | (12,660) | 86 |
Changes in securitization account | 2,856 | 7,248 |
Net cash flow used in investing activities | (215,942) | (319,798) |
Payments for (Proceeds from) Other Investing Activities | 12,660 | (86) |
Proceeds from the issuance of: | ||
Retirement of long-term debt | (9,104) | (8,856) |
Dividends paid: | ||
Payments of Ordinary Dividends, Preferred Stock and Preference Stock | 1,036 | 1,036 |
Proceeds from (Payments for) Other Financing Activities | 36,582 | 20,749 |
Net cash flow provided by financing activities | 26,442 | 10,857 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 102,920 | (675) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 124,906 | 2,822 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 65,529 | 53,019 |
Income taxes | 5,862 | 30,500 |
Capital Expenditures Incurred but Not yet Paid | 343,525 | 138,771 |
System Energy [Member] | ||
OPERATING ACTIVITIES | ||
Consolidated net income | 55,966 | 53,304 |
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities: | ||
Depreciation, amortization, and decommissioning, including nuclear fuel amortization | 106,652 | 125,741 |
Deferred income taxes, investment tax credits, and non-current taxes accrued | 28,258 | 17,865 |
Changes in working capital: | ||
Receivables | (9,335) | 13,558 |
Accounts payable | 74,527 | (26,332) |
Taxes accrued | (19,301) | (10,704) |
Interest accrued | (620) | 3,035 |
Other working capital accounts | (27,233) | 5,569 |
Changes in regulatory assets | 21,178 | (16,683) |
Increase (Decrease) in Regulatory Liabilities | (115,256) | 27,611 |
Changes in pension and other postretirement funded status | (6,952) | (4,758) |
Other Operating Activities, Cash Flow Statement | (80,464) | (127,635) |
Net cash flow provided by operating activities | 27,420 | 60,571 |
INVESTING ACTIVITIES | ||
Construction/capital expenditures | (87,410) | (54,140) |
Allowance for equity funds used during construction | 3,885 | 3,423 |
Nuclear fuel purchases | (115,544) | (31,822) |
Payments for Nuclear Fuel | (115,544) | (31,822) |
Proceeds from Nuclear Fuel | 21 | 25,091 |
Change in money pool receivable - net | (5,238) | 80,101 |
Decrease (increase) in other investments | 23 | (4) |
Proceeds from nuclear decommissioning trust fund sales | 455,082 | 151,463 |
Investment in nuclear decommissioning trust funds | (467,485) | (162,850) |
Net cash flow used in investing activities | (216,666) | 11,262 |
Payments for (Proceeds from) Other Investing Activities | (23) | 4 |
Proceeds from the issuance of: | ||
Proceeds from Issuance of Long-Term Debt | (544,736) | (585,898) |
Retirement of long-term debt | (462,226) | (612,416) |
Proceeds from Contributions from Parent | 150,000 | 0 |
Change in money pool payable - net | (12,246) | 0 |
Dividends paid: | ||
Net cash flow provided by financing activities | 220,264 | (26,518) |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total | 31,018 | 45,315 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | 31,078 | 48,255 |
Cash Paid Received During Period For [Abstract] | ||
Interest - net of amount capitalized | 25,231 | 20,289 |
Income taxes | (2,326) | 0 |
Capital Expenditures Incurred but Not yet Paid | $ 24,234 | $ 17,741 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Cash and cash equivalents: | ||
Cash | $ 82,850 | $ 71,609 |
Temporary cash investments | 1,272,314 | 60,939 |
Total cash and cash equivalents | 1,355,164 | 132,548 |
Restricted Cash and Cash Equivalents, Current | 4,000 | |
Accounts receivable: | ||
Customer | 777,791 | 699,411 |
Allowance for doubtful accounts | (16,642) | (25,905) |
Other | 227,075 | 225,334 |
Accrued unbilled revenues | 592,785 | 494,615 |
Total accounts receivable | 1,581,009 | 1,393,455 |
Deferred Fuel Cost | 78,434 | 169,967 |
Fuel inventory - at average cost | 174,475 | 192,799 |
Public Utilities, Inventory | 1,576,459 | 1,418,969 |
Prepaid Expense and Other Assets, Current | 247,056 | 213,016 |
Deferred nuclear refueling outage costs | 134,500 | 140,115 |
TOTAL | 5,147,097 | 3,660,869 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 5,265,003 | 4,863,710 |
Non-utility property - at cost (less accumulated depreciation) | 417,553 | 418,546 |
Storm Reserve Escrow Account | 332,801 | 323,206 |
Other | 71,920 | 69,494 |
TOTAL | 6,087,277 | 5,674,956 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 68,241,911 | 66,850,474 |
Natural gas | 732,677 | 717,503 |
Construction work in progress | 2,682,373 | 2,109,703 |
Nuclear fuel | 682,247 | 707,852 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 72,339,208 | 70,385,532 |
Less - accumulated depreciation and amortization | 27,171,548 | 26,551,203 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 45,167,660 | 43,834,329 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 5,408,682 | 5,669,404 |
Deferred Fuel Cost, Noncurrent | 172,201 | 172,201 |
Goodwill | 374,099 | 374,099 |
Deferred Income Tax Assets, Net | 16,510 | 16,367 |
Other | 392,771 | 301,171 |
Deferred Costs and Other Assets | 6,364,263 | 6,533,242 |
TOTAL ASSETS | 62,766,297 | 59,703,396 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 1,517,072 | 2,099,057 |
Short-Term Debt | 932,351 | 1,138,171 |
Accounts payable | 1,314,661 | 1,566,745 |
Contract with Customer, Liability, Current | 462,222 | 446,146 |
Taxes Payable, Current | 450,759 | 434,213 |
Interest accrued | 237,757 | 214,197 |
Deferred fuel costs | 262,348 | 218,927 |
Pension and other postretirement liabilities | 56,521 | 59,508 |
Other | 253,489 | 219,528 |
TOTAL | 5,487,180 | 6,396,492 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 4,321,771 | 4,245,982 |
Accumulated deferred investment tax credits | 199,745 | 205,973 |
Regulatory Liability For Income Taxes - Net | 1,042,248 | 1,033,242 |
Other regulatory liabilities | 3,488,314 | 3,116,926 |
Decommissioning and asset retirement cost liabilities | 4,683,902 | 4,505,782 |
Loss Contingency Accrual | 467,200 | 462,570 |
Pension and other postretirement liabilities | 519,861 | 648,413 |
Long-Term Debt, Excluding Current Maturities | 26,301,092 | 23,008,839 |
Deferred Credits and Other Liabilities | 1,353,919 | 1,116,661 |
TOTAL | 42,378,052 | 38,344,388 |
Commitments and Contingencies | ||
Subsidiaries’ preferred stock without sinking fund | $ 219,410 | $ 219,410 |
Preferred Stock, No Par Value | $ 0 | $ 0 |
Preferred Stock, Value, Issued | $ 0 | $ 0 |
Common Shareholders Equity [Abstract] | ||
Common Stock, Value, Issued | 2,810 | 2,810 |
Additional Paid in Capital, Common Stock | 7,785,921 | 7,795,411 |
Accumulated other comprehensive income (loss) | 80,361 | (162,460) |
Treasury Stock, Value | 4,883,695 | 4,953,498 |
TOTAL | 14,567,729 | 14,622,647 |
Equity, Attributable to Noncontrolling Interest | 113,926 | 120,459 |
Retained Earnings (Accumulated Deficit) | 11,582,332 | 11,940,384 |
TOTAL | 14,681,655 | 14,743,106 |
TOTAL LIABILITIES AND EQUITY | 62,766,297 | 59,703,396 |
Entergy Arkansas [Member] | ||
Cash and cash equivalents: | ||
Cash | 14,168 | 520 |
Temporary cash investments | 772,164 | 3,112 |
Total cash and cash equivalents | 786,332 | 3,632 |
Accounts receivable: | ||
Customer | 159,732 | 157,520 |
Allowance for doubtful accounts | (4,297) | (7,182) |
Other | 70,310 | 89,532 |
Accrued unbilled revenues | 142,619 | 117,119 |
Total accounts receivable | 545,196 | 481,661 |
Fuel inventory - at average cost | 46,605 | 57,495 |
Public Utilities, Inventory | 387,125 | 358,302 |
Prepaid Expense and Other Assets, Current | 37,288 | 40,866 |
Deferred nuclear refueling outage costs | 39,064 | 35,463 |
TOTAL | 1,841,610 | 977,419 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 1,522,508 | 1,414,009 |
Other | 799 | 801 |
TOTAL | 1,523,307 | 1,414,810 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 15,166,477 | 14,821,814 |
Construction work in progress | 503,003 | 340,601 |
Nuclear fuel | 226,459 | 213,722 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 15,895,939 | 15,376,137 |
Less - accumulated depreciation and amortization | 6,144,521 | 6,002,203 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 9,751,418 | 9,373,934 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 1,705,642 | 1,885,361 |
Other | 154,064 | 21,334 |
Deferred Costs and Other Assets | 1,859,706 | 1,906,695 |
TOTAL ASSETS | 14,976,041 | 13,672,858 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 0 | 375,000 |
Accounts Payable | 98,324 | 225,344 |
Accounts payable | 196,722 | 215,502 |
Contract with Customer, Liability, Current | 121,174 | 113,186 |
Taxes Payable, Current | 89,655 | 105,151 |
Interest accrued | 40,017 | 35,370 |
Deferred fuel costs | 90,599 | 88,282 |
Other | 65,592 | 55,683 |
TOTAL | 702,083 | 1,213,518 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 1,445,165 | 1,437,053 |
Accumulated deferred investment tax credits | 26,670 | 27,270 |
Regulatory Liability For Income Taxes - Net | 419,526 | 392,496 |
Other regulatory liabilities | 803,680 | 759,181 |
Decommissioning and asset retirement cost liabilities | 1,625,476 | 1,560,057 |
Loss Contingency Accrual | 64,684 | 58,959 |
Pension and other postretirement liabilities | 103,190 | 8,901 |
Long-Term Debt, Excluding Current Maturities | 5,094,160 | 4,298,080 |
Deferred Credits and Other Liabilities | 172,939 | 156,673 |
TOTAL | 9,755,490 | 8,698,670 |
Commitments and Contingencies | ||
Common Shareholders Equity [Abstract] | ||
Members' Equity | 4,499,793 | 3,739,071 |
Members' Equity Attributable to Noncontrolling Interest | 18,675 | 21,599 |
TOTAL | 4,518,468 | 3,760,670 |
TOTAL LIABILITIES AND EQUITY | 14,976,041 | 13,672,858 |
Entergy Arkansas [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 176,832 | 124,672 |
Entergy Louisiana [Member] | ||
Cash and cash equivalents: | ||
Cash | 474 | 2,255 |
Temporary cash investments | 185,307 | 517 |
Total cash and cash equivalents | 185,781 | 2,772 |
Accounts receivable: | ||
Customer | 302,489 | 264,776 |
Allowance for doubtful accounts | (3,361) | (6,156) |
Other | 68,394 | 74,685 |
Accrued unbilled revenues | 237,470 | 202,173 |
Total accounts receivable | 810,132 | 617,770 |
Deferred Fuel Cost | 13,436 | 24,800 |
Fuel inventory - at average cost | 50,928 | 57,818 |
Public Utilities, Inventory | 732,270 | 652,180 |
Prepaid Expense and Other Assets, Current | 240,739 | 71,613 |
Deferred nuclear refueling outage costs | 66,810 | 96,047 |
TOTAL | 2,100,096 | 1,523,000 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 2,292,174 | 2,107,384 |
Non-utility property - at cost (less accumulated depreciation) | 404,313 | 404,043 |
Storm Reserve Escrow Account | 250,372 | 243,819 |
Other | 9,587 | 9,367 |
TOTAL | 7,338,750 | 7,260,858 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 28,341,063 | 27,800,467 |
Natural gas | 324,169 | 315,658 |
Construction work in progress | 514,882 | 592,803 |
Nuclear fuel | 249,813 | 333,472 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 29,429,927 | 29,042,400 |
Less - accumulated depreciation and amortization | 10,776,257 | 10,570,707 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 18,653,670 | 18,471,693 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 1,657,857 | 1,648,852 |
Deferred Fuel Cost, Noncurrent | 168,122 | 168,122 |
Other | 52,426 | 36,945 |
Deferred Costs and Other Assets | 1,878,405 | 1,853,919 |
TOTAL ASSETS | 29,970,921 | 29,109,470 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 1,300,000 | 1,400,000 |
Accounts Payable | 132,514 | 283,016 |
Accounts payable | 406,932 | 467,414 |
Contract with Customer, Liability, Current | 172,428 | 167,905 |
Taxes Payable, Current | 94,140 | 66,463 |
Interest accrued | 105,819 | 91,656 |
Other | 107,516 | 87,468 |
TOTAL | 2,319,349 | 2,563,922 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 2,525,735 | 2,391,442 |
Accumulated deferred investment tax credits | 90,961 | 93,242 |
Regulatory Liability For Income Taxes - Net | 194,618 | 193,754 |
Other regulatory liabilities | 1,692,861 | 1,407,689 |
Decommissioning and asset retirement cost liabilities | 1,896,968 | 1,836,240 |
Loss Contingency Accrual | 273,388 | 263,869 |
Pension and other postretirement liabilities | 249,718 | 271,928 |
Long-Term Debt, Excluding Current Maturities | 8,888,393 | 8,020,689 |
Deferred Credits and Other Liabilities | 619,985 | 493,176 |
TOTAL | 16,432,627 | 14,972,029 |
Commitments and Contingencies | ||
Common Shareholders Equity [Abstract] | ||
Accumulated other comprehensive income (loss) | 50,751 | 54,798 |
Members' Equity | 11,122,661 | 11,473,614 |
Members' Equity Attributable to Noncontrolling Interest | 45,533 | 45,107 |
TOTAL | 11,218,945 | 11,573,519 |
TOTAL LIABILITIES AND EQUITY | 29,970,921 | 29,109,470 |
Entergy Louisiana [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 205,140 | 82,292 |
Investment Owned, Fair Value | 4,382,304 | 4,496,245 |
Entergy Mississippi [Member] | ||
Cash and cash equivalents: | ||
Cash | 30 | 30 |
Temporary cash investments | 3,083 | 6,600 |
Total cash and cash equivalents | 3,113 | 6,630 |
Accounts receivable: | ||
Customer | 124,274 | 121,389 |
Allowance for doubtful accounts | (2,226) | (3,312) |
Other | 22,637 | 17,697 |
Accrued unbilled revenues | 85,998 | 71,465 |
Total accounts receivable | 238,490 | 212,236 |
Fuel inventory - at average cost | 18,527 | 16,196 |
Public Utilities, Inventory | 109,283 | 95,526 |
Prepaid Expense and Other Assets, Current | 13,108 | 12,740 |
TOTAL | 382,521 | 343,328 |
OTHER PROPERTY AND INVESTMENTS | ||
Non-utility property - at cost (less accumulated depreciation) | 4,489 | 4,497 |
Storm Reserve Escrow Account | 759 | 656 |
TOTAL | 5,248 | 5,153 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 7,617,717 | 7,455,145 |
Construction work in progress | 284,846 | 139,635 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 7,902,563 | 7,594,780 |
Less - accumulated depreciation and amortization | 2,435,037 | 2,346,327 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 5,467,526 | 5,248,453 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 573,751 | 579,076 |
Other | 77,054 | 51,996 |
Deferred Costs and Other Assets | 650,805 | 631,072 |
TOTAL ASSETS | 6,506,100 | 6,228,006 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 0 | 100,000 |
Accounts Payable | 86,688 | 133,571 |
Accounts payable | 112,595 | 92,659 |
Contract with Customer, Liability, Current | 94,308 | 92,637 |
Taxes Payable, Current | 66,507 | 115,134 |
Interest accrued | 19,692 | 21,537 |
Deferred fuel costs | 171,749 | 130,645 |
Other | 22,152 | 26,463 |
TOTAL | 573,691 | 712,646 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 849,315 | 821,744 |
Accumulated deferred investment tax credits | 13,373 | 13,811 |
Regulatory Liability For Income Taxes - Net | 183,083 | 188,714 |
Other regulatory liabilities | 35,912 | 33,696 |
Decommissioning and asset retirement cost liabilities | 30,309 | 8,229 |
Loss Contingency Accrual | 27,906 | 39,481 |
Long-Term Debt, Excluding Current Maturities | 2,426,614 | 2,129,510 |
Deferred Credits and Other Liabilities | 72,986 | 71,961 |
TOTAL | 3,639,498 | 3,307,146 |
Commitments and Contingencies | ||
Common Shareholders Equity [Abstract] | ||
Members' Equity | 2,278,193 | 2,189,461 |
Members' Equity Attributable to Noncontrolling Interest | 14,718 | 18,753 |
TOTAL | 2,292,911 | 2,208,214 |
TOTAL LIABILITIES AND EQUITY | 6,506,100 | 6,228,006 |
Entergy Mississippi [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 7,807 | 4,997 |
Entergy New Orleans [Member] | ||
Cash and cash equivalents: | ||
Cash | 26 | 26 |
Temporary cash investments | 6,532 | 0 |
Total cash and cash equivalents | 6,558 | 26 |
Restricted Cash and Cash Equivalents, Current | 1,306 | 2,426 |
Accounts receivable: | ||
Customer | 71,412 | 67,258 |
Allowance for doubtful accounts | (5,824) | (7,770) |
Other | 6,883 | 5,270 |
Accrued unbilled revenues | 35,763 | 31,087 |
Total accounts receivable | 210,525 | 97,502 |
Deferred Fuel Cost | 6,199 | 6,148 |
Fuel inventory - at average cost | 2,754 | 3,298 |
Public Utilities, Inventory | 32,846 | 30,019 |
Prepaid Expense and Other Assets, Current | 19,146 | 11,482 |
Prepaid Taxes | 0 | 1,574 |
TOTAL | 279,334 | 152,475 |
OTHER PROPERTY AND INVESTMENTS | ||
Non-utility property - at cost (less accumulated depreciation) | 832 | 832 |
Storm Reserve Escrow Account | 81,670 | 78,731 |
TOTAL | 82,502 | 79,563 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 2,078,423 | 2,046,928 |
Natural gas | 408,508 | 401,846 |
Construction work in progress | 40,512 | 25,424 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 2,527,443 | 2,474,198 |
Less - accumulated depreciation and amortization | 879,838 | 858,672 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 1,647,605 | 1,615,526 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 171,294 | 182,367 |
Deferred Fuel Cost, Noncurrent | 4,080 | 4,080 |
Other | 84,269 | 63,964 |
Deferred Costs and Other Assets | 259,643 | 250,411 |
TOTAL ASSETS | 2,269,084 | 2,097,975 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 78,000 | 85,000 |
Accounts Payable | 43,275 | 76,736 |
Accounts payable | 38,150 | 39,813 |
Contract with Customer, Liability, Current | 33,324 | 32,420 |
Taxes Payable, Current | 5,771 | 0 |
Interest accrued | 7,314 | 8,534 |
Other | 11,003 | 8,953 |
TOTAL | 218,112 | 252,731 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 176,689 | 195,615 |
Accumulated deferred investment tax credits | 15,672 | 16,457 |
Regulatory Liability For Income Taxes - Net | 34,411 | 36,061 |
Other regulatory liabilities | 259,613 | 90,434 |
Loss Contingency Accrual | 90,597 | 88,124 |
Long-Term Debt, Excluding Current Maturities | 650,197 | 584,171 |
Deferred Credits and Other Liabilities | 37,882 | 20,624 |
TOTAL | 1,272,065 | 1,038,490 |
Commitments and Contingencies | ||
Common Shareholders Equity [Abstract] | ||
Members' Equity | 778,907 | 806,754 |
TOTAL | 778,907 | 806,754 |
TOTAL LIABILITIES AND EQUITY | 2,269,084 | 2,097,975 |
Notes Payable, Current | 1,275 | 1,275 |
Notes Payable, Noncurrent | 7,004 | 7,004 |
Entergy New Orleans [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 102,291 | 1,657 |
Entergy Texas [Member] | ||
Cash and cash equivalents: | ||
Cash | 26 | 1,497 |
Temporary cash investments | 124,880 | 20,489 |
Total cash and cash equivalents | 124,906 | 21,986 |
Restricted Cash and Cash Equivalents, Current | 2,340 | 5,195 |
Accounts receivable: | ||
Customer | 119,885 | 88,468 |
Allowance for doubtful accounts | (933) | (1,484) |
Other | 39,732 | 24,416 |
Accrued unbilled revenues | 90,934 | 72,771 |
Total accounts receivable | 281,550 | 514,112 |
Deferred Fuel Cost | 58,799 | 139,019 |
Fuel inventory - at average cost | 48,970 | 50,847 |
Public Utilities, Inventory | 146,412 | 123,020 |
Prepaid Expense and Other Assets, Current | 41,518 | 35,232 |
TOTAL | 704,495 | 889,411 |
OTHER PROPERTY AND INVESTMENTS | ||
Non-utility property - at cost (less accumulated depreciation) | 376 | 376 |
Other | 15,246 | 15,068 |
TOTAL | 15,752 | 15,658 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 8,144,778 | 7,931,340 |
Construction work in progress | 1,215,214 | 857,707 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 9,359,992 | 8,789,047 |
Less - accumulated depreciation and amortization | 2,472,681 | 2,363,919 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 6,887,311 | 6,425,128 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 556,409 | 596,606 |
Other | 159,392 | 129,769 |
Deferred Costs and Other Assets | 715,801 | 726,375 |
TOTAL ASSETS | 8,323,359 | 8,056,572 |
CURRENT LIABILITIES | ||
Accounts Payable | 56,359 | 74,423 |
Accounts payable | 238,679 | 195,703 |
Contract with Customer, Liability, Current | 40,988 | 39,999 |
Taxes Payable, Current | 57,732 | 78,887 |
Interest accrued | 30,724 | 31,285 |
Other | 23,979 | 16,237 |
TOTAL | 448,461 | 436,534 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 843,464 | 814,905 |
Accumulated deferred investment tax credits | 7,589 | 7,963 |
Regulatory Liability For Income Taxes - Net | 103,806 | 114,759 |
Other regulatory liabilities | 27,938 | 43,013 |
Decommissioning and asset retirement cost liabilities | 17,228 | 11,743 |
Loss Contingency Accrual | 8,096 | 9,480 |
Long-Term Debt, Excluding Current Maturities | 3,216,909 | 3,225,092 |
Deferred Credits and Other Liabilities | 405,276 | 274,421 |
TOTAL | 4,630,306 | 4,501,376 |
Commitments and Contingencies | ||
Common Stock, No Par Value | $ 0 | $ 0 |
Common Stock, Shares, Outstanding | 46,525,000 | 46,525,000 |
Common Shareholders Equity [Abstract] | ||
Common Stock, Value, Issued | $ 49,452 | $ 49,452 |
Additional Paid in Capital, Common Stock | 1,200,125 | 1,200,125 |
TOTAL | 3,205,842 | 3,079,912 |
Equity, Attributable to Noncontrolling Interest | 38,750 | 38,750 |
Retained Earnings (Accumulated Deficit) | 1,956,265 | 1,830,335 |
TOTAL | 3,244,592 | 3,118,662 |
TOTAL LIABILITIES AND EQUITY | 8,323,359 | 8,056,572 |
Entergy Texas [Member] | Affiliated Entity [Member] | ||
Accounts receivable: | ||
Customer | 31,932 | 329,941 |
Investment Owned, Fair Value | 130 | 214 |
System Energy [Member] | ||
Cash and cash equivalents: | ||
Cash | 240 | 60 |
Temporary cash investments | 30,838 | 0 |
Total cash and cash equivalents | 31,078 | 60 |
Accounts receivable: | ||
Customer | 71,436 | 54,544 |
Other | 4,542 | 6,861 |
Total accounts receivable | 75,978 | 61,405 |
Public Utilities, Inventory | 164,087 | 155,565 |
Prepaid Expense and Other Assets, Current | 8,512 | 3,373 |
Deferred nuclear refueling outage costs | 28,625 | 8,603 |
TOTAL | 308,280 | 229,006 |
OTHER PROPERTY AND INVESTMENTS | ||
Decommissioning trust funds | 1,450,321 | 1,342,317 |
TOTAL | 1,450,321 | 1,342,317 |
PROPERTY, PLANT, AND EQUIPMENT | ||
Electric | 5,597,910 | 5,495,728 |
Construction work in progress | 84,886 | 130,866 |
Nuclear fuel | 205,975 | 160,655 |
TOTAL PROPERTY, PLANT, AND EQUIPMENT | 5,888,771 | 5,787,249 |
Less - accumulated depreciation and amortization | 3,525,638 | 3,493,299 |
PROPERTY, PLANT, AND EQUIPMENT - NET | 2,363,133 | 2,293,950 |
Regulatory assets: | ||
Regulatory Asset, Noncurrent | 425,182 | 446,360 |
Other | 12,895 | 730 |
Deferred Costs and Other Assets | 438,077 | 447,090 |
TOTAL ASSETS | 4,559,811 | 4,312,363 |
CURRENT LIABILITIES | ||
Currently maturing long-term debt | 72 | 57 |
Accounts Payable | 187,787 | 118,523 |
Accounts payable | 43,623 | 73,580 |
Taxes Payable, Current | 8,100 | 27,401 |
Interest accrued | 12,334 | 12,954 |
Other | 4,351 | 4,354 |
TOTAL | 256,267 | 236,869 |
NON-CURRENT LIABILITIES | ||
Deferred Income Tax Liabilities, Net | 434,863 | 405,744 |
Accumulated deferred investment tax credits | 45,278 | 46,960 |
Regulatory Liability For Income Taxes - Net | 106,805 | 107,458 |
Other regulatory liabilities | 668,309 | 782,912 |
Decommissioning and asset retirement cost liabilities | 1,105,756 | 1,084,234 |
Pension and other postretirement liabilities | 24,711 | 19,491 |
Long-Term Debt, Excluding Current Maturities | 822,762 | 738,402 |
Deferred Credits and Other Liabilities | 555 | 1,754 |
TOTAL | 3,209,039 | 3,186,955 |
Commitments and Contingencies | ||
Common Stock, Shares, Outstanding | 789,350 | 789,350 |
Common Shareholders Equity [Abstract] | ||
Common Stock, Value, Issued | $ 1,066,850 | $ 916,850 |
Retained Earnings (Accumulated Deficit) | 27,655 | (28,311) |
TOTAL | 1,094,505 | 888,539 |
TOTAL LIABILITIES AND EQUITY | $ 4,559,811 | $ 4,312,363 |
Consolidated Statements Of Comp
Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2024 | Mar. 31, 2024 | Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | $ 51,732 | $ 76,536 | $ 392,014 | $ 312,299 | $ 128,268 | $ 704,312 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | 246,489 | (3,292) | 242,821 | (1,265) | ||
Other Comprehensive Income (Loss), Net of Tax | 246,489 | (3,668) | (3,292) | 2,027 | 242,821 | (1,265) |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 298,221 | 388,722 | 371,089 | 703,047 | ||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,810 | 770 | 4,065 | 2,133 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total | 295,411 | 387,952 | 367,024 | 700,914 | ||
Entergy Louisiana [Member] | ||||||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 131,114 | 182,723 | 263,260 | 244,024 | 313,837 | 507,284 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | (2,023) | (1,773) | (4,047) | (2,559) | ||
Other Comprehensive Income (Loss), Net of Tax | (2,023) | (2,024) | (1,773) | (786) | (4,047) | (2,559) |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 129,091 | 261,487 | 309,790 | 504,725 | ||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 788 | 819 | 1,583 | 1,373 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total | 128,303 | 260,668 | 308,207 | 503,352 | ||
Entergy Arkansas [Member] | ||||||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 95,359 | (32,280) | 66,948 | 59,397 | 63,079 | 126,344 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | (825) | (1,006) | (2,643) | (2,635) | ||
System Energy [Member] | ||||||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | $ 24,848 | $ 31,118 | $ 25,759 | $ 27,545 | $ 55,966 | $ 53,304 |
Consolidated Statements Of Chan
Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands | Total | Additional Paid-in Capital [Member] | Retained Earnings [Member] | AOCI Attributable to Parent [Member] | Common Stock [Member] | Treasury Stock, Common [Member] | Subsidiaries Preferred Stock and Noncontrolling Interests [Member] | Entergy Texas [Member] | Entergy Texas [Member] Additional Paid-in Capital [Member] | Entergy Texas [Member] Retained Earnings [Member] | Entergy Texas [Member] Common Stock [Member] | Entergy Texas [Member] Preferred Stock [Member] | Entergy Mississippi [Member] | Entergy Mississippi [Member] Member's Equity [Member] | Entergy Mississippi [Member] Noncontrolling Interest [Member] | Entergy Arkansas [Member] | Entergy Arkansas [Member] Member's Equity [Member] | Entergy Arkansas [Member] Noncontrolling Interest [Member] | Entergy Louisiana [Member] | Entergy Louisiana [Member] Restoration Law Trust II [Member] Entergy Finance Company [Member] | Entergy Louisiana [Member] Member's Equity [Member] | Entergy Louisiana [Member] AOCI Attributable to Parent [Member] | Entergy Louisiana [Member] Noncontrolling Interest [Member] | Entergy New Orleans [Member] | System Energy [Member] | System Energy [Member] Retained Earnings [Member] | System Energy [Member] Common Stock [Member] | Entergy Corporation [Member] |
Equity, Including Portion Attributable to Noncontrolling Interest | $ 13,064,892 | $ 7,632,895 | $ 10,502,041 | $ (191,754) | $ 2,797 | $ (4,978,994) | $ 97,907 | $ 2,679,461 | $ 1,050,125 | $ 1,541,134 | $ 49,452 | $ 38,750 | $ 2,040,537 | $ 2,037,190 | $ 3,347 | $ 3,781,815 | $ 3,753,990 | $ 27,825 | $ 9,493,448 | $ 9,406,343 | $ 55,370 | $ 31,735 | $ 702,816 | $ 949,767 | $ (137,083) | $ 1,086,850 | ||
Dividends, Preferred Stock, Cash | 4,580 | 0 | 0 | 0 | 0 | 0 | 4,580 | 518 | 0 | 518 | 0 | 0 | $ 4,000 | |||||||||||||||
Consolidated net income | 312,299 | 0 | 310,935 | 0 | 0 | 0 | 1,364 | 41,673 | 0 | 41,673 | 0 | 0 | 20,940 | 23,081 | (2,141) | 59,397 | 61,026 | (1,629) | 244,024 | 243,470 | 0 | 554 | 10,142 | 27,545 | 27,545 | 0 | ||
Dividends, Common Stock, Cash | (226,194) | 0 | (226,194) | 0 | 0 | 0 | 0 | (12,500) | (12,500) | 0 | (80,000) | (80,000) | 0 | (160,250) | (160,250) | 0 | 0 | |||||||||||
Noncontrolling Interest, Increase from Subsidiary Equity Issuance | 14,577 | 0 | 0 | 0 | 0 | 0 | 14,577 | 14,577 | 0 | 0 | 14,577 | |||||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (574) | 0 | 0 | 0 | 0 | 0 | (574) | (104) | 0 | (104) | (470) | 0 | 0 | (470) | ||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | 2,027 | 0 | 0 | 2,027 | 0 | 0 | 0 | (786) | 0 | (786) | 0 | |||||||||||||||||
Proceeds from Contributions from Parent | 1,457,676 | 1,457,676 | 0 | 0 | ||||||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | (4,481) | 15,118 | 0 | 0 | 0 | (19,599) | 0 | |||||||||||||||||||||
Stockholders' Equity, Other | (28) | (28) | 0 | 0 | ||||||||||||||||||||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,133 | 1,036 | (5,764) | (2,635) | 1,373 | |||||||||||||||||||||||
Consolidated net income | $ 704,312 | 130,130 | 79,205 | 126,344 | 507,284 | 23,999 | 53,304 | |||||||||||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 2.14 | |||||||||||||||||||||||||||
Payments of Ordinary Dividends, Preferred Stock and Preference Stock | $ (9,159) | (1,036) | ||||||||||||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | (1,265) | (2,559) | ||||||||||||||||||||||||||
Proceeds from Contributions from Parent | 0 | 1,457,676 | 0 | |||||||||||||||||||||||||
Proceeds from Noncontrolling Interests | 25,708 | 25,708 | ||||||||||||||||||||||||||
Equity, Including Portion Attributable to Noncontrolling Interest | 13,166,928 | 7,617,777 | 10,586,782 | (189,727) | 2,797 | (4,959,395) | 108,694 | 2,720,616 | 1,050,125 | 1,582,289 | 49,452 | 38,750 | 2,048,977 | 2,047,771 | 1,206 | 3,761,108 | 3,735,016 | 26,092 | 11,048,191 | 10,947,211 | 54,584 | 46,396 | 712,958 | 977,312 | (109,538) | 1,086,850 | ||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 770 | 518 | (3,623) | (1,006) | 819 | |||||||||||||||||||||||
Dividends, Preferred Stock, Cash | 4,580 | 0 | 0 | 0 | 0 | 0 | 4,580 | 518 | 0 | 518 | 0 | 0 | 4,000 | |||||||||||||||
Consolidated net income | 392,014 | 0 | 391,244 | 0 | 0 | 0 | 770 | 88,457 | 0 | 88,457 | 0 | 0 | 58,265 | 61,888 | (3,623) | 66,948 | 67,954 | (1,006) | 263,260 | 262,441 | 0 | 819 | 13,857 | 25,759 | 25,759 | 0 | ||
Dividends, Common Stock, Cash | (226,248) | 0 | (226,248) | 0 | 0 | 0 | 0 | (27,500) | (27,500) | 0 | (9,000) | (9,000) | 0 | |||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | $ (113) | 0 | 0 | 0 | 0 | 0 | (113) | (113) | 0 | (113) | ||||||||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 1.07 | |||||||||||||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | $ (3,292) | 0 | 0 | (3,292) | 0 | 0 | 0 | (1,773) | 0 | (1,773) | 0 | |||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | (17,128) | (16,528) | 0 | 0 | 0 | (600) | 0 | |||||||||||||||||||||
Stockholders' Equity, Other | 15 | 15 | 0 | 0 | ||||||||||||||||||||||||
Proceeds from Noncontrolling Interests | 25,708 | 0 | 0 | 0 | 0 | 0 | 25,708 | 25,708 | 0 | 25,708 | ||||||||||||||||||
Equity, Including Portion Attributable to Noncontrolling Interest | 13,367,545 | 7,634,305 | 10,751,778 | (193,019) | 2,797 | (4,958,795) | 130,479 | 2,808,555 | 1,050,125 | 1,670,228 | 49,452 | 38,750 | 2,105,450 | 2,082,159 | 23,291 | 3,818,943 | 3,793,970 | 24,973 | 11,309,693 | 11,209,667 | 52,811 | 47,215 | 726,815 | 1,003,071 | (83,779) | 1,086,850 | ||
Equity, Including Portion Attributable to Noncontrolling Interest | 14,743,106 | 7,795,411 | 11,940,384 | (162,460) | 2,810 | (4,953,498) | 120,459 | 3,118,662 | 1,200,125 | 1,830,335 | 49,452 | 38,750 | 2,208,214 | 2,189,461 | 18,753 | 3,760,670 | 3,739,071 | 21,599 | 11,573,519 | 11,473,614 | 54,798 | 45,107 | 806,754 | 888,539 | (28,311) | 916,850 | ||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | $ 1,500,000 | |||||||||||||||||||||||||||
Dividends, Preferred Stock, Cash | 4,580 | 0 | 0 | 0 | 0 | 0 | 4,580 | 518 | 0 | 518 | 0 | 0 | 4,000 | |||||||||||||||
Consolidated net income | 76,536 | 0 | 75,281 | 0 | 0 | 0 | 1,255 | 36,744 | 0 | 36,744 | 0 | 0 | 27,432 | 29,734 | (2,302) | (32,280) | (30,462) | (1,818) | 182,723 | 181,928 | 0 | 795 | (48,980) | 31,118 | 31,118 | 0 | ||
Dividends, Common Stock, Cash | (240,959) | 0 | (240,959) | 0 | 0 | 0 | 0 | (97,500) | (97,500) | 0 | 0 | |||||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (1,108) | 0 | 0 | 0 | 0 | 0 | (1,108) | (250) | 0 | (250) | (858) | 0 | 0 | (858) | ||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | (3,668) | 0 | 0 | (3,668) | 0 | 0 | 0 | (2,024) | 0 | (2,024) | 0 | |||||||||||||||||
Proceeds from Contributions from Parent | 275,000 | 275,000 | 0 | 150,000 | 0 | 150,000 | ||||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | (5,039) | 25,842 | 0 | 0 | 0 | (30,881) | 0 | |||||||||||||||||||||
Stockholders' Equity, Other | (43) | (43) | 0 | 0 | ||||||||||||||||||||||||
Noncash Capital Contribution from Parent | 976 | 976 | 0 | 0 | ||||||||||||||||||||||||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 4,065 | 1,036 | (4,035) | (2,643) | 1,583 | |||||||||||||||||||||||
Consolidated net income | $ 128,268 | 126,966 | 106,997 | 63,079 | 313,837 | (27,847) | 55,966 | |||||||||||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 2.26 | |||||||||||||||||||||||||||
Payments of Ordinary Dividends, Preferred Stock and Preference Stock | $ (9,159) | (1,036) | ||||||||||||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | 242,821 | (4,047) | ||||||||||||||||||||||||||
Proceeds from Contributions from Parent | 695,000 | 0 | 150,000 | |||||||||||||||||||||||||
Proceeds from Noncontrolling Interests | 0 | 0 | ||||||||||||||||||||||||||
Equity, Including Portion Attributable to Noncontrolling Interest | 14,574,366 | 7,769,569 | 11,774,706 | (166,128) | 2,810 | (4,922,617) | 116,026 | 3,154,888 | 1,200,125 | 1,866,561 | 49,452 | 38,750 | 2,235,646 | 2,219,195 | 16,451 | 4,003,140 | 3,983,609 | 19,531 | 11,656,793 | 11,558,975 | 52,774 | 45,044 | 757,774 | 1,069,657 | 2,807 | 1,066,850 | ||
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,810 | 518 | (1,733) | (825) | 788 | |||||||||||||||||||||||
Dividends, Preferred Stock, Cash | 4,580 | 0 | 0 | 0 | 0 | 0 | 4,580 | 518 | 0 | 518 | 0 | 0 | $ 4,000 | |||||||||||||||
Consolidated net income | 51,732 | 0 | 48,922 | 0 | 0 | 0 | 2,810 | 90,222 | 0 | 90,222 | 0 | 0 | 79,565 | 81,298 | (1,733) | 95,359 | 96,184 | (825) | 131,114 | 130,326 | 0 | 788 | 21,133 | 24,848 | 24,848 | 0 | ||
Dividends, Common Stock, Cash | (241,296) | 0 | (241,296) | 0 | 0 | 0 | 0 | (22,300) | (22,300) | 0 | (566,600) | (566,600) | 0 | 0 | ||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | $ (330) | 0 | 0 | 0 | 0 | 0 | (330) | (31) | 0 | (31) | (299) | 0 | 0 | (299) | ||||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 1.13 | |||||||||||||||||||||||||||
Other Comprehensive Income (Loss), Net of Tax | $ 246,489 | 0 | 0 | 246,489 | 0 | 0 | 0 | (2,023) | 0 | (2,023) | 0 | |||||||||||||||||
Proceeds from Contributions from Parent | 420,000 | 420,000 | 0 | |||||||||||||||||||||||||
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture | (55,274) | (16,352) | 0 | 0 | 0 | (38,922) | 0 | |||||||||||||||||||||
Stockholders' Equity, Other | (40) | (40) | 0 | 0 | ||||||||||||||||||||||||
Equity, Including Portion Attributable to Noncontrolling Interest | $ 14,681,655 | $ 7,785,921 | $ 11,582,332 | $ 80,361 | $ 2,810 | $ (4,883,695) | $ 113,926 | $ 3,244,592 | $ 1,200,125 | $ 1,956,265 | $ 49,452 | $ 38,750 | $ 2,292,911 | $ 2,278,193 | $ 14,718 | $ 4,518,468 | $ 4,499,793 | $ 18,675 | $ 11,218,945 | $ 11,122,661 | $ 50,751 | $ 45,533 | $ 778,907 | $ 1,094,505 | $ 27,655 | $ 1,066,850 | ||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | $ 1,500,000 |
Consolidated Balance Sheets (Pa
Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Securitized Regulatory Transition Assets, Noncurrent | $ 243,478 | $ 250,830 |
Long-Term Transition Bond, Noncurrent | $ 248,670 | $ 263,007 |
Preferred Stock, Shares Issued | 0 | 0 |
Preferred Stock, Shares Authorized | 1,000,000 | 1,000,000 |
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 | 280,975,348 |
Treasury Stock, Common, Shares | 67,166,752 | 68,126,778 |
Prepaid Expense and Other Assets, Current | $ 247,056 | $ 213,016 |
Commitments and Contingencies | ||
Cash and Cash Equivalents, at Carrying Value | 1,355,164 | 132,548 |
Cash | 82,850 | 71,609 |
Entergy Texas [Member] | ||
Securitized Regulatory Transition Assets, Noncurrent | 243,478 | 250,324 |
Long-Term Transition Bond, Noncurrent | $ 248,670 | $ 257,592 |
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 |
Prepaid Expense and Other Assets, Current | $ 41,518 | $ 35,232 |
Commitments and Contingencies | ||
Common Stock, No Par Value | $ 0 | $ 0 |
Cash and Cash Equivalents, at Carrying Value | $ 124,906 | $ 21,986 |
Cash | 26 | 1,497 |
Entergy New Orleans [Member] | ||
Securitized Regulatory Transition Assets, Noncurrent | 0 | 506 |
Long-Term Transition Bond, Noncurrent | 0 | 5,415 |
Prepaid Expense and Other Assets, Current | 19,146 | 11,482 |
Commitments and Contingencies | ||
Prepaid Taxes | 0 | 1,574 |
Cash and Cash Equivalents, at Carrying Value | 6,558 | 26 |
Cash | $ 26 | $ 26 |
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 |
Prepaid Expense and Other Assets, Current | $ 8,512 | $ 3,373 |
Commitments and Contingencies | ||
Cash and Cash Equivalents, at Carrying Value | 31,078 | 60 |
Cash | $ 240 | $ 60 |
Consolidated Statements of Co_2
Consolidated Statements of Comprehensive Income (Parentheticals) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Other Comprehensive (Income) Loss, Defined Benefit Plan, before Reclassification Adjustment, Tax | $ 65,371 | $ (1,065) | $ 64,170 | $ (335) |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,810 | 770 | 4,065 | 2,133 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | 295,411 | 387,952 | 367,024 | 700,914 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 51,732 | 392,014 | 128,268 | 704,312 |
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | 246,489 | (3,292) | 242,821 | (1,265) |
Other Comprehensive Income (Loss), Net of Tax | 246,489 | (3,292) | 242,821 | (1,265) |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 298,221 | 388,722 | 371,089 | 703,047 |
Entergy Louisiana [Member] | ||||
Other Comprehensive (Income) Loss, Defined Benefit Plan, before Reclassification Adjustment, Tax | 745 | 653 | 1,491 | 943 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 788 | 819 | 1,583 | 1,373 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | 128,303 | 260,668 | 308,207 | 503,352 |
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | 131,114 | 263,260 | 313,837 | 507,284 |
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | (2,023) | (1,773) | (4,047) | (2,559) |
Other Comprehensive Income (Loss), Net of Tax | (2,023) | (1,773) | (4,047) | (2,559) |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | $ 129,091 | $ 261,487 | $ 309,790 | $ 504,725 |
Commitments and Contingencies
Commitments and Contingencies | 6 Months Ended |
Jun. 30, 2024 | |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
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, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf - Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. Nelson Industrial Steam Company (Entergy Louisiana) See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Nelson Industrial Steam Company partnership. |
Rate And Regulatory Matters
Rate And Regulatory Matters | 6 Months Ended |
Jun. 30, 2024 | |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
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 See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2024, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease in the rate from $0.01883 per kWh to $0.00882 per kWh. Due to a change in law in the State of Arkansas, the annual redetermination included $9 million, recorded as a credit to fuel expense in first quarter 2024, for recovery attributed to net metering costs in 2023. The primary reason for the rate decrease is a large over-recovered balance as a result of lower natural gas prices in 2023. To mitigate the effect of projected increases in natural gas prices in 2024, Entergy Arkansas adjusted the over-recovered balance included in the March 2024 annual redetermination filing by $43.7 million. This adjustment is expected to reduce the rate change that will be reflected in the 2025 energy cost rate redetermination. The redetermined rate of $0.00882 per kWh became effective with the first billing cycle in April 2024 through the normal operation of the tariff. Entergy Mississippi In June 2024 the MPSC approved a joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “ Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2024 Formula Rate Plan Filing In July 2024, Entergy Arkansas filed with the APSC its 2024 formula rate plan filing to set its formula rate for the 2025 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the 2025 projected year and a netting adjustment for the 2023 historical year. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2025 projected year was 8.43% resulting in a revenue deficiency of $69.5 million. The earned rate of return on common equity for the 2023 historical year was 7.48% resulting in a $33.1 million netting adjustment. The total proposed revenue change for the 2025 projected year and 2023 historical year netting adjustment is $102.6 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $82.6 million. This filing is subject to review by the APSC, which is expected to issue its order on the filing in December 2024. Grand Gulf Credit Rider In June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “ Complaints Against System Energy - System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlement. In July 2024 the APSC approved the tariff, under which Entergy Arkansas will refund retail customers a total of $100.6 million with a one-time bill credit during the August 2024 billing cycle. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request As discussed in the Form 10-K, in August 2023, Entergy Louisiana filed an application for approval of a regulatory blueprint necessary for it to strengthen the electric grid for the State of Louisiana, which contains a dual-path request to update rates through either: (1) extension of Entergy Louisiana’s current formula rate plan (with certain modifications) for three years (the Rate Mitigation Proposal), which is Entergy Louisiana’s recommended path; or (2) implementation of rates resulting from a cost-of-service study (the Rate Case path). The application complies with Entergy Louisiana’s previous formula rate plan extension order requiring that for Entergy Louisiana to obtain another extension of its formula rate plan that included a rate reset, Entergy Louisiana would need to submit a full cost-of-service/rate case. Entergy Louisiana’s filing supports the need to extend Entergy Louisiana’s formula rate plan with credit supportive mechanisms needed to facilitate investment in the distribution, transmission, and generation functions. A status conference was held in October 2023 at which a procedural schedule was adopted that included three technical conferences and a hearing in August 2024. In March 2024 the parties agreed to an eight-week extension of all deadlines to allow for continuation of settlement negotiations, and the ALJ issued an order with an amended procedural schedule. In July 2024 the parties agreed to extend further the procedural schedule to facilitate the continuation of settlement negotiations, with the hearing commencing in December 2024. In July 2024, Entergy Louisiana reached an agreement in principle with the LPSC staff and the intervenors in the proceeding and filed with the LPSC a joint motion to suspend the procedural schedule to allow for all parties to finalize a stipulated settlement agreement. In August 2024, Entergy Louisiana and the LPSC staff jointly filed a global stipulated settlement agreement for consideration by the LPSC with key terms as follows: • continuation of the formula rate plan for 2024-2026 (test years 2023-2025); • a base formula rate plan revenue increase of $120 million for test year 2023, effective for rates beginning September 2024; • a $140 million cumulative cap on base formula rate plan revenue increases, if needed, for test years 2024 and 2025, excluding outside the bandwidth items; • $184 million of customer rate credits to be given over two years, including increasing customer sharing of income tax benefits resulting from the 2016-2018 IRS audit, to resolve any remaining disputed issues stemming from formula rate plan test years prior to test year 2023, including but not limited to the investigation into Entergy Services costs billed to Entergy Louisiana. As discussed in Note 3 to the financial statements in the Form 10-K, a $38 million regulatory liability was recorded in 2023 in connection with the 2016-2018 IRS audit; • $75.8 million of customer rate credits, as provided for in the System Energy global settlement, to be credited over three years subject to and conditioned upon FERC approval of the System Energy global settlement. See “ Complaints Against System Energy – System Energy Settlement with the LPSC ” below for further details of the System Energy global settlement; • $5.8 million of customer rate credits provided for in the Entergy Louisiana formula rate plan global settlement agreement approved by the LPSC in November 2023 credited over one year. See Note 2 to the financial statements in the Form 10-K for the discussion of the November 2023 Entergy Louisiana formula rate plan global settlement agreement; • an increase in the allowed midpoint return on common equity from 9.5% to 9.7%, with a bandwidth of 40 basis points above and below the midpoint, for the extended term of the formula rate plan, except that for test year 2023 in which the authorized return on common equity shall have no bearing on the change in base formula rate plan revenue described above and, for test year 2024, any earnings above the authorized return on common equity shall be returned to customers through a credit; • an increase in nuclear depreciation rates by $15 million in each of the 2023, 2024, and 2025 test years outside of the formula rate plan bandwidth calculation; and • for the transmission recovery mechanism and the distribution recovery mechanism, no change to the existing floors, but the caps for both would be $350 million for test year 2023, $375 million for test year 2024, and $400 million for test year 2025. LPSC-approved transmission projects will be exempt from the transmission recovery mechanism cap. The terms of the global stipulated settlement agreement are subject to approval by the LPSC and will not go into effect unless/until such approval is obtained. Entergy Louisiana anticipates the global stipulated settlement agreement to be considered by the LPSC at its Business and Executive meeting on August 14, 2024. Based on the July 2024 agreement in principle, in second quarter 2024 Entergy Louisiana recorded expenses of $151 million ($111 million net-of-tax) primarily consisting of regulatory charges to reflect the effects of the agreement in principle. Filings with the MPSC (Entergy Mississippi) Retail Rates 2024 Formula Rate Plan Filing In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024. In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates. In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation. Also, in May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with recently passed state legislation. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed its interim facilities rate adjustment report in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Filings with the City Council (Entergy New Orleans) Retail Rates 2024 Formula Rate Plan Filing In April 2024, Entergy New Orleans submitted to the City Council its formula rate plan 2023 test year filing. Without the requested rate change in 2024, the 2023 test year evaluation report produced an electric earned return on equity of 8.66% and a gas earned return on equity of 5.87% compared to the authorized return on equity for each of 9.35%. Entergy New Orleans seeks approval of a $12.6 million rate increase based on the formula set by the City Council in the 2018 rate case and approved again by the City Council in 2023. The formula would result in an increase in authorized electric revenues of $7.0 million and an increase in authorized gas revenues of $5.6 million. Following City Council review, the City Council’s advisors issued a report in July 2024 seeking a reduction in Entergy New Orleans’s requested formula rate plan revenues in an aggregate amount of approximately $1.6 million for electric and gas together due to alleged errors. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. Resulting rates will be effective with the first billing cycle of September 2024 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a procedural schedule that would extend the process for City Council approval of disputed rate adjustments. Filings with the PUCT and Texas Cities (Entergy Texas) Retail Rates 2022 Base Rate Case As discussed in the Form 10-K, in August 2023 the PUCT issued an order severing issues related to electric vehicle charging infrastructure in the 2022 base rate case proceeding to a separate proceeding. In December 2023 the PUCT referred the separate proceeding to resolve the issues related to electric vehicle charging infrastructure to the State Office of Administrative Hearings. A hearing on the merits was held in April 2024. In June 2024 the ALJ with the State Office of Administrative Hearings issued a proposal for decision concluding that it is appropriate for a vertically integrated electric utility, and Entergy Texas specifically, to own vehicle-charging facilities or other transportation electrification and charging infrastructure and recommending that both of Entergy Texas’s proposed transportation electrification riders be approved. A PUCT decision is expected in third quarter 2024. Distribution Cost Recovery Factor (DCRF) Rider In June 2024, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $40.3 million annually based on its capital invested in distribution between January 1, 2022 and March 31, 2024. The PUCT adopted a procedural schedule in July 2024. A PUCT decision is expected in third quarter 2024. Entergy Arkansas Opportunity Sales Proceeding See Note 2 to the financial statements in the Form 10-K for discussion of the Entergy Arkansas opportunity sales proceeding. As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023. Following the trial, Entergy Arkansas filed a motion with the United States Court of Appeals for the Eighth District to expedite the appeal filed by Arkansas Electric Energy Consumers, Inc. The United States Court of Appeals for the Eighth District granted Entergy Arkansas’s request, and oral arguments were held in June 2023. In August 2023 the United States Court of Appeals for the Eighth District affirmed the order of the court denying Arkansas Electric Energy Consumers, Inc.’s motion to intervene. In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth District and the court granted the motion to expedite. Briefing to the United States Court of Appeals for the Eighth District concluded in July 2024. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. MSS-4 Replacement Tariff – Net Operating Loss Carryforward Proceeding In January 2021, pursuant to section 205 of the Federal Power Act, Entergy Services filed an amendment to the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity between the Utility operating companies, in order to provide for the inclusion of specified accumulated deferred income taxes, including net operating loss carryforward accumulated deferred income taxes (NOLC ADIT), in the rate for sales of energy among the Utility operating companies on a prospective basis. In March 2021, the FERC accepted the filing, subject to refund and hearing procedures. In October 2021 the LPSC filed a complaint with the FERC alleging that Entergy Services improperly excluded NOLC ADIT from MSS-4 replacement tariff rates in the period before March 20, 2021. The LPSC argued that sales from Entergy Louisiana to Entergy Texas and Entergy New Orleans were charged at rates lower than they otherwise should have been, and it accordingly seeks surcharges for the period prior to March 20, 2021. The FERC set the complaint for hearing procedures and subsequently the hearing for this complaint proceeding was consolidated with the hearing procedures for Entergy Services’ January 2021 NOLC ADIT filing. Testimony was filed by parties in 2023, and the hearing before a FERC ALJ was concluded in February 2024. In June 2024, the FERC ALJ issued an initial decision addressing three major issues: (1) whether Entergy Services’ proposed prospective inclusion and allocation of NOLC ADIT in MSS-4 replacement tariff rates using a modified with-and-without methodology is just and reasonable; (2) whether Entergy Services correctly calculated excess and deficient accumulated deferred income taxes in accordance with the terms of a prior settlement; and (3) whether NOLC ADIT should have been included in MSS-4 replacement tariff rates prior to the effective date of the January 2021 MSS-4 replacement tariff filing. With respect to issues (1) and (2), the presiding ALJ concluded that Entergy Services’ proposed methodology for allocating and including NOLC ADIT in MSS-4 replacement tariff rates was just and reasonable and that Entergy Services correctly performed the excess and deficient accumulated deferred income taxes calculations. With respect to issue (3), however, the presiding ALJ agreed with the LPSC that NOLC ADIT should have been included in MSS-4 replacement tariff rates since September 1, 2016, and as a result, the presiding ALJ ordered that Entergy Louisiana and Entergy Arkansas recalculate bills for the period of September 1, 2016 through November 11, 2023 with surcharges expected to be due to those operating companies from the purchasing operating companies, Entergy New Orleans, Entergy Texas, and Entergy Louisiana (for some Entergy Arkansas sales). The presiding ALJ also ordered Entergy Services to pay the interest owed to Entergy Louisiana on these surcharges. The surcharge methodology that the presiding ALJ recommended in connection with issue (3) was not supported by any participant in the hearing. As part of their exceptions to the initial decision, all parties to the proceeding opposed the use of the ALJ’s methodology, except for the FERC trial staff, which took no position. During the hearing, the LPSC and the FERC trial staff advocated that the alleged tariff violation should be remedied by the application of Entergy Services’ January 2021 proposed methodology. All other parties, including the PUCT, the City Council, and Entergy Services, opposed any surcharges for the period prior to the March 20, 2021 effective date of the January 2021 filing. Entergy Services disputes the presiding ALJ's rulings on issue (3) and filed exceptions to these rulings in July 2024. The ALJ's initial decision is not binding on the FERC and is an interim step in the hearing process. No refunds will be owed in connection with this proceeding unless and until the FERC requires them in a final order. Complaints Against System Energy See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy. System Energy and the Unit Power Sales Agreement are currently the subject of several litigation proceedings at the FERC (or on appeal from the FERC to the United States Court of Appeals for the Fifth Circuit) , including challenges with respect to System Energy’s authorized return on equity and capital structure, renewal of its sale-leaseback arrangement, treatment of uncertain tax positions, a broader investigation of rates under the Unit Power Sales Agreement, and two prudence complaints, one challenging the extended power uprate completed at Grand Gulf in 2012 and the operation and management of Grand Gulf, particularly in the 2016-2020 time period, and the second challenging the operation and management of Grand Gulf in the 2021-2022 time period. S ettlements that resolve all significant aspects of these complaints have been reached with the MPSC and the APSC and approved by the FERC. A settlement has been reached with the City Council and is pending FERC approval, as described in “ System Energy Settlement with the City Council ” below. An agreement in principle has been reached with the LPSC staff, as described in “ System Energy Settlement with the LPSC ” below. If the settlement with the City Council is approved by the FERC and the settlement with the LPSC staff is approved by the LPSC and the FERC, it would resolve all significant aspects of these pending complaints. The following are updates to the discussion in the Form 10-K. Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in March 2021 the FERC ALJ issued an initial decision in the proceeding initiated by the LPSC, the MPSC, the APSC, and the City Council against System Energy regarding the return on equity component of the Unit Power Sales Agreement. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the FERC’s Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $25.3 million, which includes interest through June 30, 2024, and the estimated resulting annual rate reduction would be approximately $15 million. As a result of the settlement agreements with the MPSC and the APSC, both the estimated refund and rate reduction exclude Entergy Mississippi's and Entergy Arkansas’s portions. See “ System Energy Settlement with the MPSC ” in the Form 10-K and see “ System Energy Settlement with the APSC ” below and in the Form 10-K for discussion of the settlements. The estimated refund will continue to accrue interest until a final FERC decision is issued. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021 the LPSC, the APSC, the MPSC, the City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, the APSC, the MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. The APSC, the MPSC, and the City Council subsequently intervened in the proceeding. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision, and in December 2022 the FERC issued an order on the ALJ’s initial decision, which affirmed it in part and modified it in part. The FERC’s order directed System Energy to calculate refunds on three issues, and to provide a compliance report detailing the calculations. The FERC’s order also disallows the future recovery of sale-leaseback renewal costs, which is estimated at approximately $11.5 million annually for purchases from Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans through July 2036. The three refund issues are rental expenses related to the renewal of the sale-leaseback arrangements; refunds, if any, for the revenue requirement impact of including accumulated deferred income taxes resulting from the decommissioning uncertain tax positions from 2004 through the present; and refunds for the net effect of correcting the depreciation inputs for capital additions attributable to the portion of plant subject to the sale-leaseback. In January 2023, System Energy filed its compliance report with the FERC. With respect to the sale-leaseback renewal costs, System Energy calculated a refund of $89.8 million, which represented all of the sale-leaseback renewal rental costs that System Energy recovered in rates, with interest. With respect to the decommissioning uncertain tax position issue, System Energy calculated that no additional refunds are owed because it had already provided a one-time historical credit (for the period January 2016 through September 2020) of $25.2 million based on the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position, and because it has been providing an ongoing rate base credit for the accumulated deferred income taxes that resulted from the IRS’s partial acceptance of the decommissioning tax position since October 2020. With respect to the depreciation refund, System Energy calculated a refund of $13.7 million, which is the net total of a refund to customers for excess depreciation expense previously collected, plus interest, offset by the additional return on rate base that System Energy previously did not collect, without interest. In January 2023, System Energy filed a request for rehearing of the FERC’s determinations in the December 2022 order on sale-leaseback refund issues and future lease cost disallowances, the FERC’s prospective policy on uncertain tax positions, and the proper accounting of System Energy’s accumulated deferred income taxes adjustment for the Tax Cuts and Jobs Act of 2017; and a motion for confirmation of its interpretation of the December 2022 order’s remedy concerning the decommissioning tax position. In January 2023 the retail regulators filed a motion for confirmation of their interpretation of the refund requirement in the December 2022 FERC order and a provisional request for rehearing. In February 2023 the FERC issued a notice that the rehearing requests have been deemed denied by operation of law. The deemed denial of the rehearing request initiated a sixty-day period in which aggrieved parties could petition for federal appellate court review of the underlying FERC orders; however, the FERC may issue a substantive order on rehearing as long as it continues to have jurisdiction over the case. In March 2023, System Energy filed in the United States Court of Appeals for the Fifth Circuit a petition for review of the December 2022 order. In March 2023, System Energy also filed an unopposed motion to stay the proceeding in the Fifth Circuit pending the FERC’s disposition of the pending motions, and the court granted the motion to stay. In August 2023 the FERC issued an order addressing arguments raised on rehearing and partially setting aside the prior order (rehearing order). The rehearing order addresses rehearing requests that were filed in January 2023 separately by System Energy and the LPSC, the APSC, and the City Council. In the rehearing order, the FERC directs System Energy to recalculate refunds for two issues: (1) refunds of rental expenses related to the renewal of the sale-leaseback arrangements and (2) refunds for the net effect of correcting the depreciation inputs for capital additions associated with the sale-leaseback. With regard to the sale-leaseback renewal rental expenses, the rehearing order allows System Energy to recover an implied return of and on the depreciated cost of the portion of the plant subject to the sale-leaseback as of the expiration of the initial lease term. With regard to the depreciation input issue, the rehearing order allows System Energy to offset refunds so that S |
Equity
Equity | 6 Months Ended |
Jun. 30, 2024 | |
Equity [Text Block] | EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2024 and 2023, included on the consolidated income statements: For the Three Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $51,732 $392,014 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 2,810 770 Net income attributable to Entergy Corporation $48,922 $391,244 Basic shares and earnings per average common share 213.6 $0.23 211.4 $1.85 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.4 $0.23 212.2 $1.84 For the Six Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $128,268 $704,312 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 4,065 2,133 Net income attributable to Entergy Corporation $124,203 $702,179 Basic shares and earnings per average common share 213.4 $0.58 211.4 $3.32 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.2 $0.58 212.2 $3.31 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,448,982 options for the three months ended June 30, 2024 and 1,315,567 options for the three months ended June 30, 2023. The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,471,220 options for the six months ended June 30, 2024 and 1,248,743 options for the six months ended June 30, 2023. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $1.13 for the three months ended June 30, 2024 and $1.07 for the three months ended June 30, 2023. Dividends declared per common share were $2.26 for the six months ended June 30, 2024 and $2.14 for the six months ended June 30, 2023. Equity Distribution Program See Note 7 to the financial statements in the Form 10-K for discussion of Entergy Corporation’s at the market equity distribution program. The following are updates to that discussion. In May 2024, Entergy Corporation entered into an amendment to the equity distribution sales agreement for its at the market equity distribution program wherein it increased by an additional $1 billion the aggregate gross sales price authorized under the at the market equity distribution program from $2 billion to $3 billion and added additional agents, forward purchasers, and forward sellers. 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 $3 billion. As of June 30, 2024, an aggregate gross sales price of approximately $2 billion has been sold under the at the market equity distribution program. During the six months ended June 30, 2024 and 2023, there were no shares of common stock issued under the at the market equity distribution program. In March 2024, Entergy Corporation entered into two separate forward sale agreements for 284,922 shares and 1,160,415 shares of common stock, respectively. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transactions by issuing the total of 284,922 shares and 1,160,415 shares, respectively, of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the applicable agreement (initially approximately $101.92 and $101.74 per share, respectively) or (ii) net settle the applicable transaction in whole or in part through the delivery or receipt of cash or shares. Each 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 applicable agreement. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 284,922 shares and 1,160,415 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $29.3 million and $119.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward seller fees of approximately $0.3 million and $1.2 million, respectively, which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In May 2024, Entergy Corporation entered into two separate forward sale agreements for 1,278,416 shares and 1,233,235 shares of common stock, respectively. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy Corporation to, at its election prior to July 31, 2025, either (i) physically settle the transactions by issuing the total of 1,278,416 shares and 1,233,235 shares, respectively, of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the applicable agreement (initially approximately $110.32 and $107.93 per share, respectively) or (ii) net settle the applicable transaction in whole or in part through the delivery or receipt of cash or shares. Each 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 applicable agreement. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,278,416 shares and 1,233,235 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $142.4 million and $134.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward seller fees of approximately $1.4 million and $1.3 million, respectively, which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In June 2024, Entergy Corporation entered into a forward sale agreement for 1,070,003 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 July 31, 2025, either (i) physically settle the transaction by issuing the total of 1,070,003 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 $106.12 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 1,070,003 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $114.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward seller fees of approximately $1.1 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 occurs, earnings per share dilution resulting from the agreements, if any, is 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. For the three months ended June 30, 2024 and 2023, 1,094,239 shares and 156,101 shares, respectively, under current and then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. For the six months ended June 30, 2024 and 2023, 1,502,247 and 78,050 shares, respectively, under current and then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Treasury Stock During the six months ended June 30, 2024, Entergy Corporation reissued 10,757 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2024. Retained Earnings On July 26, 2024, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.13 per share, payable on September 3, 2024 to holders of record as of August 13, 2024. 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 three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, ($166,128) ($189,727) Amounts reclassified from accumulated other comprehensive income (loss) 246,489 (3,292) Net other comprehensive income (loss) for the period 246,489 (3,292) Ending balance, June 30, $80,361 ($193,019) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, ($162,460) ($191,754) Amounts reclassified from accumulated other comprehensive income (loss) 242,821 (1,265) Net other comprehensive income (loss) for the period 242,821 (1,265) Ending balance, June 30, $80,361 ($193,019) The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, $52,774 $54,584 Amounts reclassified from accumulated other comprehensive income (2,023) (1,773) Net other comprehensive loss for the period (2,023) (1,773) Ending balance, June 30, $50,751 $52,811 The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, $54,798 $55,370 Amounts reclassified from accumulated other comprehensive income (4,047) (2,559) Net other comprehensive loss for the period (4,047) (2,559) Ending balance, June 30, $50,751 $52,811 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $3,473 $3,398 (a) Amortization of net gain 1,641 1,633 (a) Settlement loss (316,974) (674) (a) Total amortization and settlement loss (311,860) 4,357 Income taxes 65,371 (1,065) Income taxes Total amortization and settlement loss (net of tax) ($246,489) $3,292 Total reclassifications for the period (net of tax) ($246,489) $3,292 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $6,946 $6,795 (a) Amortization of net gain 3,037 3,295 (a) Settlement loss (316,974) (8,490) (a) Total amortization and settlement loss (306,991) 1,600 Income taxes 64,170 (335) Income taxes Total amortization and settlement loss (net of tax) ($242,821) $1,265 Total reclassifications for the period (net of tax) ($242,821) $1,265 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $1,136 $951 (a) Amortization of net gain 1,632 1,564 (a) Settlement loss — (89) (a) Total amortization and settlement loss 2,768 2,426 Income taxes (745) (653) Income taxes Total amortization and settlement loss (net of tax) 2,023 1,773 Total reclassifications for the period (net of tax) $2,023 $1,773 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $2,272 $1,902 (a) Amortization of net gain 3,266 3,129 (a) Settlement loss — (1,529) (a) Total amortization and settlement loss 5,538 3,502 Income taxes (1,491) (943) Income taxes Total amortization and settlement loss (net of tax) 4,047 2,559 Total reclassifications for the period (net of tax) $4,047 $2,559 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. |
Entergy Louisiana [Member] | |
Equity [Text Block] | EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings per Share The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2024 and 2023, included on the consolidated income statements: For the Three Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $51,732 $392,014 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 2,810 770 Net income attributable to Entergy Corporation $48,922 $391,244 Basic shares and earnings per average common share 213.6 $0.23 211.4 $1.85 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.4 $0.23 212.2 $1.84 For the Six Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $128,268 $704,312 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 4,065 2,133 Net income attributable to Entergy Corporation $124,203 $702,179 Basic shares and earnings per average common share 213.4 $0.58 211.4 $3.32 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.2 $0.58 212.2 $3.31 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,448,982 options for the three months ended June 30, 2024 and 1,315,567 options for the three months ended June 30, 2023. The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,471,220 options for the six months ended June 30, 2024 and 1,248,743 options for the six months ended June 30, 2023. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $1.13 for the three months ended June 30, 2024 and $1.07 for the three months ended June 30, 2023. Dividends declared per common share were $2.26 for the six months ended June 30, 2024 and $2.14 for the six months ended June 30, 2023. Equity Distribution Program See Note 7 to the financial statements in the Form 10-K for discussion of Entergy Corporation’s at the market equity distribution program. The following are updates to that discussion. In May 2024, Entergy Corporation entered into an amendment to the equity distribution sales agreement for its at the market equity distribution program wherein it increased by an additional $1 billion the aggregate gross sales price authorized under the at the market equity distribution program from $2 billion to $3 billion and added additional agents, forward purchasers, and forward sellers. 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 $3 billion. As of June 30, 2024, an aggregate gross sales price of approximately $2 billion has been sold under the at the market equity distribution program. During the six months ended June 30, 2024 and 2023, there were no shares of common stock issued under the at the market equity distribution program. In March 2024, Entergy Corporation entered into two separate forward sale agreements for 284,922 shares and 1,160,415 shares of common stock, respectively. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy Corporation to, at its election prior to May 30, 2025, either (i) physically settle the transactions by issuing the total of 284,922 shares and 1,160,415 shares, respectively, of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the applicable agreement (initially approximately $101.92 and $101.74 per share, respectively) or (ii) net settle the applicable transaction in whole or in part through the delivery or receipt of cash or shares. Each 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 applicable agreement. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 284,922 shares and 1,160,415 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $29.3 million and $119.2 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward seller fees of approximately $0.3 million and $1.2 million, respectively, which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In May 2024, Entergy Corporation entered into two separate forward sale agreements for 1,278,416 shares and 1,233,235 shares of common stock, respectively. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offerings until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy Corporation to, at its election prior to July 31, 2025, either (i) physically settle the transactions by issuing the total of 1,278,416 shares and 1,233,235 shares, respectively, of its common stock to the forward counterparty in exchange for net proceeds at the then-applicable forward sale price specified by the applicable agreement (initially approximately $110.32 and $107.93 per share, respectively) or (ii) net settle the applicable transaction in whole or in part through the delivery or receipt of cash or shares. Each 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 applicable agreement. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 1,278,416 shares and 1,233,235 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $142.4 million and $134.4 million, respectively. In connection with the sales of these shares, Entergy Corporation paid the forward seller fees of approximately $1.4 million and $1.3 million, respectively, which have not been deducted from the gross sales price. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. In June 2024, Entergy Corporation entered into a forward sale agreement for 1,070,003 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 July 31, 2025, either (i) physically settle the transaction by issuing the total of 1,070,003 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 $106.12 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 1,070,003 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled approximately $114.5 million. In connection with the sale of these shares, Entergy Corporation paid the forward seller fees of approximately $1.1 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 occurs, earnings per share dilution resulting from the agreements, if any, is 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. For the three months ended June 30, 2024 and 2023, 1,094,239 shares and 156,101 shares, respectively, under current and then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. For the six months ended June 30, 2024 and 2023, 1,502,247 and 78,050 shares, respectively, under current and then-outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Treasury Stock During the six months ended June 30, 2024, Entergy Corporation reissued 10,757 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2024. Retained Earnings On July 26, 2024, Entergy Corporation’s Board of Directors declared a common stock dividend of $1.13 per share, payable on September 3, 2024 to holders of record as of August 13, 2024. 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 three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, ($166,128) ($189,727) Amounts reclassified from accumulated other comprehensive income (loss) 246,489 (3,292) Net other comprehensive income (loss) for the period 246,489 (3,292) Ending balance, June 30, $80,361 ($193,019) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, ($162,460) ($191,754) Amounts reclassified from accumulated other comprehensive income (loss) 242,821 (1,265) Net other comprehensive income (loss) for the period 242,821 (1,265) Ending balance, June 30, $80,361 ($193,019) The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, $52,774 $54,584 Amounts reclassified from accumulated other comprehensive income (2,023) (1,773) Net other comprehensive loss for the period (2,023) (1,773) Ending balance, June 30, $50,751 $52,811 The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, $54,798 $55,370 Amounts reclassified from accumulated other comprehensive income (4,047) (2,559) Net other comprehensive loss for the period (4,047) (2,559) Ending balance, June 30, $50,751 $52,811 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $3,473 $3,398 (a) Amortization of net gain 1,641 1,633 (a) Settlement loss (316,974) (674) (a) Total amortization and settlement loss (311,860) 4,357 Income taxes 65,371 (1,065) Income taxes Total amortization and settlement loss (net of tax) ($246,489) $3,292 Total reclassifications for the period (net of tax) ($246,489) $3,292 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $6,946 $6,795 (a) Amortization of net gain 3,037 3,295 (a) Settlement loss (316,974) (8,490) (a) Total amortization and settlement loss (306,991) 1,600 Income taxes 64,170 (335) Income taxes Total amortization and settlement loss (net of tax) ($242,821) $1,265 Total reclassifications for the period (net of tax) ($242,821) $1,265 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $1,136 $951 (a) Amortization of net gain 1,632 1,564 (a) Settlement loss — (89) (a) Total amortization and settlement loss 2,768 2,426 Income taxes (745) (653) Income taxes Total amortization and settlement loss (net of tax) 2,023 1,773 Total reclassifications for the period (net of tax) $2,023 $1,773 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $2,272 $1,902 (a) Amortization of net gain 3,266 3,129 (a) Settlement loss — (1,529) (a) Total amortization and settlement loss 5,538 3,502 Income taxes (1,491) (943) Income taxes Total amortization and settlement loss (net of tax) 4,047 2,559 Total reclassifications for the period (net of tax) $4,047 $2,559 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. |
Revolving Credit Facilities, Li
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt | 6 Months Ended |
Jun. 30, 2024 | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Entergy Arkansas [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Entergy Louisiana [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Entergy Mississippi [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Entergy New Orleans [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Entergy Texas [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
System Energy [Member] | |
Debt Disclosure [Text Block] | REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (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 billion and expires in June 2029. 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. As there were no borrowings under the facility for the six months ended June 30, 2024, the estimated interest rate as of June 30, 2024 that would have been applied to outstanding borrowings under the facility was 6.94%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 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 June 30, 2024, Entergy Corporation had $932.4 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2024 was 5.67%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $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 June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— 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 June 30, 2024, $139 million in cash borrowings were outstanding under the credit facility. The weighted-average interest rate for the six months ended June 30, 2024 was 6.95% 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 in the Form 10-K 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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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 and guarantor 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 June 30, 2024, 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 VIE. Debt Issuances and Retirements (Entergy Corporation) In May 2024, Entergy Corporation issued $1.2 billion of junior subordinated debentures due December 2054. Entergy Corporation will pay interest at an annual rate of 7.125% through November 2029. Commencing on December 1, 2029, the annual rate will equal the five-year treasury rate as of the most recent reset interest determination date plus 2.67%. Entergy Corporation used the proceeds to repay a portion of outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In May 2024, Entergy Arkansas issued $400 million of 5.45% Series mortgage bonds due June 2034 and $400 million of 5.75% Series mortgage bonds due June 2054. Entergy Arkansas used a portion of the proceeds, together with other funds, to repay, at maturity, its $375 million of 3.70% Series mortgage bonds due June 2024 and to repay borrowings from the Entergy system money pool. Entergy Arkansas expects to use the remaining proceeds, together with other funds, to repay a portion of the purchase price of each of Driver Solar, Walnut Bend Solar, and/or West Memphis Solar, and for general corporate purposes. (Entergy Louisiana) In March 2024, Entergy Louisiana issued $500 million of 5.35% Series mortgage bonds due March 2034 and $700 million of 5.70% Series mortgage bonds due March 2054. Entergy Louisiana used a portion of the proceeds, together with other funds, to repay in March 2024 debt outstanding under its long-term revolving credit facility and to repay in April 2024, prior to maturity, its $400 million of 5.40% Series mortgage bonds due November 2024. Entergy Louisiana expects to use the remaining proceeds, together with other funds, to repay, at or prior to maturity, its $1 billion of 0.95% Series mortgage bonds due October 2024, for capital expenditures, and for general corporate purposes. (Entergy Mississippi) In May 2024, Entergy Mississippi issued $300 million of 5.85% Series mortgage bonds due June 2054. Entergy Mississippi used the proceeds, together with other funds, to repay in June 2024, prior to maturity, its $100 million of 3.75% Series mortgage bonds due July 2024, to repay debt incurred under its long-term revolving credit facility, to repay borrowings from the Entergy system money pool, and for general corporate purposes. (Entergy New Orleans) In April 2024, Entergy New Orleans entered into a bond purchase agreement related to the sale of $150 million of mortgage bonds to be issued in May 2024. In May 2024, Entergy New Orleans issued (1) $35 million of 6.25% Series mortgage bonds due June 2029, (2) $65 million of 6.41% Series mortgage bonds due June 2031, and (3) $50 million of 6.54% Series mortgage bonds due June 2034. Entergy New Orleans used the proceeds, together with other funds, to repay, at maturity, its $85 million unsecured term loan due June 2024 and for general corporate purposes. Fair Value The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Stock-Based Compensation
Stock-Based Compensation | 6 Months Ended |
Jun. 30, 2024 | |
Share-Based Payment Arrangement [Text Block] | STOCK-BASED COMPENSATION (Entergy Corporation) Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K. Awards under Entergy’s plans generally vest over three years. Stock Options In January 2024 the Board approved and Entergy granted long-term incentive awards in the form of options on 352,199 shares of its common stock under the 2019 Omnibus Incentive Plan with a fair value of $18.61 per option. As of June 30, 2024, there were options on 2,599,829 shares of common stock outstanding with a weighted-average exercise price of $101.84. The intrinsic value, which has no effect on net income, of the outstanding stock options 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 June 30, 2024. The aggregate intrinsic value of the stock options outstanding as of June 30, 2024 was $25.7 million. The following table includes financial information for stock options for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $1.1 $1.1 Tax benefit recognized in Entergy’s consolidated net income $0.3 $0.3 Compensation cost capitalized as part of fixed assets and materials and supplies $0.5 $0.6 The following table includes financial information for stock options for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $2.2 $2.1 Tax benefit recognized in Entergy’s consolidated net income $0.6 $0.6 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0 $1.1 Other Equity Awards In January 2024 the Board approved and Entergy granted long-term incentive awards in the form of 409,947 restricted stock awards and 158,176 performance units under the 2019 Omnibus Incentive Plan. The restricted stock awards were made effective on January 25, 2024 and were valued at $99.08 per share, which was the closing price of Entergy Corporation’s common stock on that date. Shares of restricted stock 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 three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date. The performance units represent 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. To emphasize the importance of environmental stewardship, specifically of carbon-free generation and resilience, an environmental achievement measure was selected as one of the performance measures for the 2024-2026 performance period. Performance will be based eighty percent on relative total shareholder return and twenty percent on the environmental achievement measure. The performance units were granted on January 25, 2024 and eighty percent were valued at $124.65 per share based on various factors, primarily market conditions; and twenty percent were valued at $99.08 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 and are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period, and compensation cost for the portion of the award based on the selected environmental achievement measure will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program. The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $9.8 $10.1 Tax benefit recognized in Entergy’s consolidated net income $2.5 $2.6 Compensation cost capitalized as part of fixed assets and materials and supplies $4.6 $4.4 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $19.7 $17.8 Tax benefit recognized in Entergy’s consolidated net income $5.0 $4.6 Compensation cost capitalized as part of fixed assets and materials and supplies $9.1 $7.6 |
Retirement And Other Postretire
Retirement And Other Postretirement Benefits | 6 Months Ended |
Jun. 30, 2024 | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Arkansas [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Louisiana [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Mississippi [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy New Orleans [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Texas [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
System Energy [Member] | |
Retirement Benefits [Text Block] | RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 Non-Qualified Net Pension Cost Entergy recognized $2.7 million and $8.8 million in pension cost for its non-qualified pension plans for the second quarters of 2024 and 2023, respectively. For the second quarter of 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost for non-qualified pension plans for the second quarter of 2023 were settlement charges of $4.6 million related to the payment of lump sum benefits out of the plans. Entergy recognized $5.4 million and $18 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2024 and 2023, respectively. For the six months ended June 30, 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Included in the pension cost non-qualified pension plans for the six months ended June 30, 2023 were settlement charges of $9.3 million related to the payment of lump sum benefits out of the plans. The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 For the second quarters of 2024 and 2023, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan. For the six months ended June 30, 2023, there were settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, included in the non-qualified pension costs above related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefits Cost (Income) Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 Accounting for Pension and Other Postretirement Benefits In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Qualified Pension Settlement Costs In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.157 billion of benefit liabilities of the Pension Plans. The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments beginning September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans. The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge in the second quarter of 2024 of $325 million, of which $8 million was recorded at Utility, as described below, and $317 million was recorded at Parent & Other. The $317 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements. For the six months ended June 30, 2023, lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2023 service and interest cost, resulting in settlement costs. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy each participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, to track the surplus or deficit in the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amounts recorded are evaluated in each rate case filed by Entergy Texas and an amortization period is determined at that time. See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs. Employer Contributions Based on current assumptions, Entergy expects to contribute $270 million to its qualified pension plans in 2024. As of June 30, 2024, Entergy had contributed $111.4 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Business Segment Information
Business Segment Information | 6 Months Ended |
Jun. 30, 2024 | |
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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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 for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. 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. |
Risk Management And Fair Values
Risk Management And Fair Values | 6 Months Ended |
Jun. 30, 2024 | |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 commodity and financial 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 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 Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments. 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 June 30, 2024 is 9 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of June 30, 2024 is 10,988,500 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. 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 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. 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 June 30, 2024 is 133,533 GWh for Entergy, including 31,900 GWh for Entergy Arkansas, 57,200 GWh for Entergy Louisiana, 19,179 GWh for Entergy Mississippi, 5,469 GWh for Entergy New Orleans, and 19,448 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 Entergy’s 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 June 30, 2024 and December 31, 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2024 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2023. The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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. 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 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 tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 Entergy Louisiana 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 Entergy Mississippi 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 Entergy New Orleans 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 Entergy Texas 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 (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 9 to the financial statements herein 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
Decommissioning Trust Funds
Decommissioning Trust Funds | 6 Months Ended |
Jun. 30, 2024 | |
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. 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. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $78 million and $366 million, respectively. 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $1,922 $10 $139 2023 Debt Securities $1,770 $19 $134 As of June 30, 2024 and December 31, 2023, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,051 million as of June 30, 2024 and $1,885 million as of December 31, 2023. As of June 30, 2024, available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.14 years, and an average maturity of approximately 10.44 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $453 $5 $134 $6 More than 12 months 949 134 999 128 Total $1,402 $139 $1,133 $134 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $76 $82 1 year - 5 years 568 517 5 years - 10 years 575 504 10 years - 15 years 120 121 15 years - 20 years 186 179 20 years+ 397 367 Total $1,922 $1,770 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $161 million and $136 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $14 million and $8 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $330 million and $260 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $1 million in each period and gross losses of $20 million and $17 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.4 $1.9 $59.0 2023 Debt Securities $496.9 $2.4 $53.6 The amortized cost of available-for-sale debt securities was $611.5 million as of June 30, 2024 and $548.1 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 2.92%, an average duration of approximately 5.80 years, and an average maturity of approximately 7.51 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $21.7 million and $105.7 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $70.8 $1.1 $22.5 $0.4 More than 12 months 388.7 57.9 403.4 53.2 Total $459.5 $59.0 $425.9 $53.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $43.5 $45.3 1 year - 5 years 156.3 132.2 5 years - 10 years 234.8 205.7 10 years - 15 years 31.7 39.9 15 years - 20 years 59.8 49.6 20 years+ 28.3 24.2 Total $554.4 $496.9 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $5.5 million and $0.9 million, respectively. During the three months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.4 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $0.1 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $17.9 million and $16.6 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2023, there were no gross gains and gross losses of $1.7 million related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $812.6 $4.6 $39.8 2023 Debt Securities $788.1 $11.7 $37.4 The amortized cost of available-for-sale debt securities was $847.8 million as of June 30, 2024 and $813.9 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 4.03%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.79 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $42.3 million and $166.6 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $275.6 $2.7 $69.8 $0.9 More than 12 months 340.4 37.1 356.1 36.5 Total $616.0 $39.8 $425.9 $37.4 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $27.3 $31.4 1 year - 5 years 189.2 181.6 5 years - 10 years 186.9 170.0 10 years - 15 years 79.8 70.2 15 years - 20 years 84.7 90.2 20 years+ 244.7 244.7 Total $812.6 $788.1 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $65.2 million, respectively. During the three months ended June 30, 2024 and 2023, there were gross gains of $0.1 million in each period and gross losses of $4.8 million and $4 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $110.9 million and $132.6 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $0.2 million and $0.5 million, respectively, and gross losses of $7.7 million and $9 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.6 $3.2 $40.2 2023 Debt Securities $485.2 $4.5 $42.5 The amortized cost of available-for-sale debt securities was $591.6 million as of June 30, 2024 and $523.2 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 3.78%, an average duration of approximately 6.18 years, and an average maturity of approximately 10.03 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $14.3 million and $93.3 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $106.8 $1.6 $42.1 $4.5 More than 12 months 219.8 38.6 239.1 38.0 Total $326.6 $40.2 $281.2 $42.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $5.4 $5.3 1 year - 5 years 222.1 203.4 5 years - 10 years 153.5 128.6 10 years - 15 years 8.1 10.7 15 years - 20 years 41.0 38.8 20 years+ 124.5 98.4 Total $554.6 $485.2 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $93.5 million and $69.9 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $8.4 million and $4.1 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $201.5 million and $111.2 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.2 million and gross losses of $11.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $6.3 million related to available-for-sale debt securities reclassified out of 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. 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. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $78 million and $366 million, respectively. 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $1,922 $10 $139 2023 Debt Securities $1,770 $19 $134 As of June 30, 2024 and December 31, 2023, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,051 million as of June 30, 2024 and $1,885 million as of December 31, 2023. As of June 30, 2024, available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.14 years, and an average maturity of approximately 10.44 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $453 $5 $134 $6 More than 12 months 949 134 999 128 Total $1,402 $139 $1,133 $134 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $76 $82 1 year - 5 years 568 517 5 years - 10 years 575 504 10 years - 15 years 120 121 15 years - 20 years 186 179 20 years+ 397 367 Total $1,922 $1,770 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $161 million and $136 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $14 million and $8 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $330 million and $260 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $1 million in each period and gross losses of $20 million and $17 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.4 $1.9 $59.0 2023 Debt Securities $496.9 $2.4 $53.6 The amortized cost of available-for-sale debt securities was $611.5 million as of June 30, 2024 and $548.1 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 2.92%, an average duration of approximately 5.80 years, and an average maturity of approximately 7.51 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $21.7 million and $105.7 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $70.8 $1.1 $22.5 $0.4 More than 12 months 388.7 57.9 403.4 53.2 Total $459.5 $59.0 $425.9 $53.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $43.5 $45.3 1 year - 5 years 156.3 132.2 5 years - 10 years 234.8 205.7 10 years - 15 years 31.7 39.9 15 years - 20 years 59.8 49.6 20 years+ 28.3 24.2 Total $554.4 $496.9 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $5.5 million and $0.9 million, respectively. During the three months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.4 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $0.1 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $17.9 million and $16.6 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2023, there were no gross gains and gross losses of $1.7 million related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $812.6 $4.6 $39.8 2023 Debt Securities $788.1 $11.7 $37.4 The amortized cost of available-for-sale debt securities was $847.8 million as of June 30, 2024 and $813.9 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 4.03%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.79 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $42.3 million and $166.6 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $275.6 $2.7 $69.8 $0.9 More than 12 months 340.4 37.1 356.1 36.5 Total $616.0 $39.8 $425.9 $37.4 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $27.3 $31.4 1 year - 5 years 189.2 181.6 5 years - 10 years 186.9 170.0 10 years - 15 years 79.8 70.2 15 years - 20 years 84.7 90.2 20 years+ 244.7 244.7 Total $812.6 $788.1 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $65.2 million, respectively. During the three months ended June 30, 2024 and 2023, there were gross gains of $0.1 million in each period and gross losses of $4.8 million and $4 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $110.9 million and $132.6 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $0.2 million and $0.5 million, respectively, and gross losses of $7.7 million and $9 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.6 $3.2 $40.2 2023 Debt Securities $485.2 $4.5 $42.5 The amortized cost of available-for-sale debt securities was $591.6 million as of June 30, 2024 and $523.2 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 3.78%, an average duration of approximately 6.18 years, and an average maturity of approximately 10.03 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $14.3 million and $93.3 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $106.8 $1.6 $42.1 $4.5 More than 12 months 219.8 38.6 239.1 38.0 Total $326.6 $40.2 $281.2 $42.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $5.4 $5.3 1 year - 5 years 222.1 203.4 5 years - 10 years 153.5 128.6 10 years - 15 years 8.1 10.7 15 years - 20 years 41.0 38.8 20 years+ 124.5 98.4 Total $554.6 $485.2 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $93.5 million and $69.9 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $8.4 million and $4.1 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $201.5 million and $111.2 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.2 million and gross losses of $11.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $6.3 million related to available-for-sale debt securities reclassified out of 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. 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. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $78 million and $366 million, respectively. 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $1,922 $10 $139 2023 Debt Securities $1,770 $19 $134 As of June 30, 2024 and December 31, 2023, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,051 million as of June 30, 2024 and $1,885 million as of December 31, 2023. As of June 30, 2024, available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.14 years, and an average maturity of approximately 10.44 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $453 $5 $134 $6 More than 12 months 949 134 999 128 Total $1,402 $139 $1,133 $134 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $76 $82 1 year - 5 years 568 517 5 years - 10 years 575 504 10 years - 15 years 120 121 15 years - 20 years 186 179 20 years+ 397 367 Total $1,922 $1,770 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $161 million and $136 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $14 million and $8 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $330 million and $260 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $1 million in each period and gross losses of $20 million and $17 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.4 $1.9 $59.0 2023 Debt Securities $496.9 $2.4 $53.6 The amortized cost of available-for-sale debt securities was $611.5 million as of June 30, 2024 and $548.1 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 2.92%, an average duration of approximately 5.80 years, and an average maturity of approximately 7.51 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $21.7 million and $105.7 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $70.8 $1.1 $22.5 $0.4 More than 12 months 388.7 57.9 403.4 53.2 Total $459.5 $59.0 $425.9 $53.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $43.5 $45.3 1 year - 5 years 156.3 132.2 5 years - 10 years 234.8 205.7 10 years - 15 years 31.7 39.9 15 years - 20 years 59.8 49.6 20 years+ 28.3 24.2 Total $554.4 $496.9 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $5.5 million and $0.9 million, respectively. During the three months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.4 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $0.1 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $17.9 million and $16.6 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2023, there were no gross gains and gross losses of $1.7 million related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $812.6 $4.6 $39.8 2023 Debt Securities $788.1 $11.7 $37.4 The amortized cost of available-for-sale debt securities was $847.8 million as of June 30, 2024 and $813.9 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 4.03%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.79 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $42.3 million and $166.6 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $275.6 $2.7 $69.8 $0.9 More than 12 months 340.4 37.1 356.1 36.5 Total $616.0 $39.8 $425.9 $37.4 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $27.3 $31.4 1 year - 5 years 189.2 181.6 5 years - 10 years 186.9 170.0 10 years - 15 years 79.8 70.2 15 years - 20 years 84.7 90.2 20 years+ 244.7 244.7 Total $812.6 $788.1 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $65.2 million, respectively. During the three months ended June 30, 2024 and 2023, there were gross gains of $0.1 million in each period and gross losses of $4.8 million and $4 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $110.9 million and $132.6 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $0.2 million and $0.5 million, respectively, and gross losses of $7.7 million and $9 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.6 $3.2 $40.2 2023 Debt Securities $485.2 $4.5 $42.5 The amortized cost of available-for-sale debt securities was $591.6 million as of June 30, 2024 and $523.2 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 3.78%, an average duration of approximately 6.18 years, and an average maturity of approximately 10.03 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $14.3 million and $93.3 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $106.8 $1.6 $42.1 $4.5 More than 12 months 219.8 38.6 239.1 38.0 Total $326.6 $40.2 $281.2 $42.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $5.4 $5.3 1 year - 5 years 222.1 203.4 5 years - 10 years 153.5 128.6 10 years - 15 years 8.1 10.7 15 years - 20 years 41.0 38.8 20 years+ 124.5 98.4 Total $554.6 $485.2 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $93.5 million and $69.9 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $8.4 million and $4.1 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $201.5 million and $111.2 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.2 million and gross losses of $11.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $6.3 million related to available-for-sale debt securities reclassified out of 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. 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. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $78 million and $366 million, respectively. 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $1,922 $10 $139 2023 Debt Securities $1,770 $19 $134 As of June 30, 2024 and December 31, 2023, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,051 million as of June 30, 2024 and $1,885 million as of December 31, 2023. As of June 30, 2024, available-for-sale debt securities had an average coupon rate of approximately 3.63%, an average duration of approximately 6.14 years, and an average maturity of approximately 10.44 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $453 $5 $134 $6 More than 12 months 949 134 999 128 Total $1,402 $139 $1,133 $134 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $76 $82 1 year - 5 years 568 517 5 years - 10 years 575 504 10 years - 15 years 120 121 15 years - 20 years 186 179 20 years+ 397 367 Total $1,922 $1,770 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $161 million and $136 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $14 million and $8 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $330 million and $260 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $1 million in each period and gross losses of $20 million and $17 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.4 $1.9 $59.0 2023 Debt Securities $496.9 $2.4 $53.6 The amortized cost of available-for-sale debt securities was $611.5 million as of June 30, 2024 and $548.1 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 2.92%, an average duration of approximately 5.80 years, and an average maturity of approximately 7.51 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $21.7 million and $105.7 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $70.8 $1.1 $22.5 $0.4 More than 12 months 388.7 57.9 403.4 53.2 Total $459.5 $59.0 $425.9 $53.6 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $43.5 $45.3 1 year - 5 years 156.3 132.2 5 years - 10 years 234.8 205.7 10 years - 15 years 31.7 39.9 15 years - 20 years 59.8 49.6 20 years+ 28.3 24.2 Total $554.4 $496.9 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $5.5 million and $0.9 million, respectively. During the three months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.4 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $0.1 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $17.9 million and $16.6 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.1 million and gross losses of $0.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2023, there were no gross gains and gross losses of $1.7 million related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $812.6 $4.6 $39.8 2023 Debt Securities $788.1 $11.7 $37.4 The amortized cost of available-for-sale debt securities was $847.8 million as of June 30, 2024 and $813.9 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 4.03%, an average duration of approximately 6.36 years, and an average maturity of approximately 12.79 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $42.3 million and $166.6 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $275.6 $2.7 $69.8 $0.9 More than 12 months 340.4 37.1 356.1 36.5 Total $616.0 $39.8 $425.9 $37.4 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $27.3 $31.4 1 year - 5 years 189.2 181.6 5 years - 10 years 186.9 170.0 10 years - 15 years 79.8 70.2 15 years - 20 years 84.7 90.2 20 years+ 244.7 244.7 Total $812.6 $788.1 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $65.2 million, respectively. During the three months ended June 30, 2024 and 2023, there were gross gains of $0.1 million in each period and gross losses of $4.8 million and $4 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale securities amounted to $110.9 million and $132.6 million, respectively. During the six months ended June 30, 2024 and 2023, there were gross gains of $0.2 million and $0.5 million, respectively, and gross losses of $7.7 million and $9 million, respectively, related to available-for-sale debt securities reclassified out of 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 June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.6 $3.2 $40.2 2023 Debt Securities $485.2 $4.5 $42.5 The amortized cost of available-for-sale debt securities was $591.6 million as of June 30, 2024 and $523.2 million as of December 31, 2023. As of June 30, 2024, the available-for-sale debt securities had an average coupon rate of approximately 3.78%, an average duration of approximately 6.18 years, and an average maturity of approximately 10.03 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2024 on equity securities still held as of June 30, 2024 were $14.3 million and $93.3 million, respectively. 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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $106.8 $1.6 $42.1 $4.5 More than 12 months 219.8 38.6 239.1 38.0 Total $326.6 $40.2 $281.2 $42.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $5.4 $5.3 1 year - 5 years 222.1 203.4 5 years - 10 years 153.5 128.6 10 years - 15 years 8.1 10.7 15 years - 20 years 41.0 38.8 20 years+ 124.5 98.4 Total $554.6 $485.2 During the three months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $93.5 million and $69.9 million, respectively. During the three months ended June 30, 2024 and 2023, there were no gross gains and gross losses of $8.4 million and $4.1 million, respectively, related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2024 and 2023, proceeds from the dispositions of available-for-sale debt securities amounted to $201.5 million and $111.2 million, respectively. During the six months ended June 30, 2024, there were gross gains of $0.2 million and gross losses of $11.9 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. During the three months ended June 30, 2023, there were no gross gains and gross losses of $6.3 million related to available-for-sale debt securities reclassified out of other regulatory liabilities/assets into earnings. |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2024 | |
Income Tax Disclosure [Text Block] | INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
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) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Income Tax Audits As discussed in Note 3 to the financial statements in the Form 10-K, in November 2023 the IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report for each federal filer under audit. Based on prior regulatory agreements and general rate-making principles, in fourth quarter 2023 Entergy New Orleans recorded a regulatory liability and associated regulatory charge of $60 million ($44 million net-of-tax). In April 2024, Entergy New Orleans and the City Council entered into a settlement in principle whereby Entergy New Orleans agreed to share with customers $138 million of income tax benefits from the resolution of the 2016–2018 IRS audit. Based on this settlement in principle, in first quarter 2024 Entergy New Orleans increased the associated regulatory liability from $60 million to $138 million and recorded a corresponding $78 million regulatory charge ($57 million net-of-tax). The settlement in principle requires that the regulatory liability be amortized over 25 years with the unamortized balance included in rate base and the amortization treated as a reduction to Entergy New Orleans’s retail revenue requirement. In May 2024 the City Council approved the settlement. Arkansas Corporate Income Tax Rate Change In June 2024, Arkansas Act 1 of the Second Extraordinary Session reduced the Arkansas corporate income tax rate from 4.8% to 4.3%, which is retroactively effective as of January 1, 2024. As a result of the rate reduction, Entergy Arkansas accrued a regulatory liability for income taxes of approximately $31 million in the second quarter of 2024. The regulatory liability includes a tax gross-up related to the treatment of income taxes in the retail and wholesale ratemaking formulas and is expected to be included in future rate mechanisms. |
Variable Interest Entities
Variable Interest Entities | 6 Months Ended |
Jun. 30, 2024 | |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
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) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs). See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests. Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust I was $2.9 billion and $3 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 LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $30.6 million as of June 30, 2024 and $30.5 million as of December 31, 2023. Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2024 and December 31, 2023, the primary asset held by the storm trust II was $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 LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.9 million as of June 30, 2024 and $14.6 million as of December 31, 2023. 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 in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2024 and the six months ended June 30, 2023. 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. As of June 30, 2024, AR Searcy Partnership, LLC recorded assets equal to $132.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $112.9 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas. 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. As of June 30, 2024, MS Sunflower Partnership, LLC recorded assets equal to $167.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $131.1 million. 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. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi. |
Revenue Recognition
Revenue Recognition | 6 Months Ended |
Jun. 30, 2024 | |
Revenue from Contract with Customer [Text Block] | REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. 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 six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 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 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. |
Asset Retirement Obligations
Asset Retirement Obligations | 6 Months Ended |
Jun. 30, 2024 | |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
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) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. Nuclear Plant Decommissioning In first quarter 2024, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $14.4 million decrease in its decommissioning cost liabilities, along with corresponding decreases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy coal combustion residuals (CCR) surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31 million and $9 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified. |
Business Combinations and Asset
Business Combinations and Asset Acquisitions | 6 Months Ended |
Jun. 30, 2024 | |
Asset Acquisition [Line Items] | |
Asset Acquisition [Text Block] | ACQUISITIONS (Entergy Corporation and Entergy Arkansas) 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 approximately $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 2024, at which time a substantial completion payment of approximately $20 million is expected. |
Entergy Arkansas [Member] | |
Asset Acquisition [Line Items] | |
Asset Acquisition [Text Block] | ACQUISITIONS (Entergy Corporation and Entergy Arkansas) 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 approximately $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 2024, at which time a substantial completion payment of approximately $20 million is expected. |
Insider Trading Arrangements
Insider Trading Arrangements | 3 Months Ended |
Jun. 30, 2024 shares | |
Trading Arrangements, by Individual | |
Non-Rule 10b5-1 Arrangement Adopted | false |
Non-Rule 10b5-1 Arrangement Terminated | false |
Andrew Marsh [Member] | |
Trading Arrangements, by Individual | |
Material Terms of Trading Arrangement | On May 6, 2024, Andrew S. Marsh, Chair of the Board and Chief Executive Officer of Entergy, adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense of Rule 10b5-1(c) with respect to options which will be expiring within the next two years. Mr. Marsh’s Rule 10b5-1 trading arrangement provides for (a) 24,000 shares to be acquired by option exercise and subsequently sold on or prior to January 29, 2025 (the date on which those options expire) and (b) 45,000 shares to be acquired by option exercise and subsequently sold on or prior to January 28, 2026 (the date on which those options expire), each in accordance with the terms specified in the trading arrangement. The term of Mr. Marsh’s Rule 10b5-1 trading arrangement expires on January 28, 2026. The first date that any transactions under Mr. Marsh’s Rule 10b5-1 trading arrangement can occur is August 5, 2024. |
Name | Andrew S. Marsh |
Title | Chair of the Board and Chief Executive Officer of Entergy |
Rule 10b5-1 Arrangement Adopted | true |
Adoption Date | May 6, 2024 |
Haley Fisackerly [Member] | |
Trading Arrangements, by Individual | |
Material Terms of Trading Arrangement | On May 8, 2024, Haley Fisackerly, Chairman of the Board, President, and Chief Executive Officer of Entergy Mississippi, terminated a Rule 10b5-1 trading arrangement he had previously adopted on March 6, 2024, which was intended to satisfy the affirmative defense of Rule 10b5-1(c), had a term expiring on December 31, 2024, and provided for the sale of up to 1,000 shares of Entergy’s common stock pursuant to the terms of the trading arrangement. As of the date of termination of the trading arrangement, Mr. Fisackerly had not sold any shares of common stock under its terms. |
Name | Haley Fisackerly |
Title | Chairman of the Board, President, and Chief Executive Officer of Entergy Mississippi |
Rule 10b5-1 Arrangement Terminated | true |
Termination Date | May 8, 2024 |
Aggregate Available | 1,000 |
Peter S. Norgeot, Jr. [Member] | |
Trading Arrangements, by Individual | |
Material Terms of Trading Arrangement | On May 10, 2024, Peter S. Norgeot, Jr., Executive Vice President and Chief Operating Officer of Entergy and a director of Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas, adopted a Rule 10b5-1 trading arrangement that is intended to satisfy the affirmative defense of Rule 10b5-1(c) with respect to previously granted and fully vested options. Mr. Norgeot’s Rule 10b5-1 trading arrangement provides for up to 34,495 shares to be acquired by option exercise and subsequently sold until May 9, 2025 in accordance with the terms specified in the trading arrangement. The first date that any transactions under Mr. Norgeot’s Rule 10b5-1 trading arrangement can occur is August 8, 2024. |
Name | Peter S. Norgeot, Jr. |
Title | Executive Vice President and Chief Operating Officer of Entergy and a director of Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas |
Rule 10b5-1 Arrangement Adopted | true |
Adoption Date | May 10, 2024 |
Aggregate Available | 34,495 |
Expiring within one year [Member] | Andrew Marsh [Member] | |
Trading Arrangements, by Individual | |
Aggregate Available | 24,000 |
Expiring within two years [Member] | Andrew Marsh [Member] | |
Trading Arrangements, by Individual | |
Aggregate Available | 45,000 |
Equity (Tables)
Equity (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block] | The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2024 and 2023, included on the consolidated income statements: For the Three Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $51,732 $392,014 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 2,810 770 Net income attributable to Entergy Corporation $48,922 $391,244 Basic shares and earnings per average common share 213.6 $0.23 211.4 $1.85 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.4 $0.23 212.2 $1.84 For the Six Months Ended June 30, 2024 2023 (Dollars In Thousands, Except Per Share Data; Shares in Millions) $/share $/share Consolidated net income $128,268 $704,312 Less: Preferred dividend requirements of subsidiaries and noncontrolling interests 4,065 2,133 Net income attributable to Entergy Corporation $124,203 $702,179 Basic shares and earnings per average common share 213.4 $0.58 211.4 $3.32 Average dilutive effect of: Stock options 0.3 — 0.3 — Other equity plans 0.5 — 0.5 (0.01) Diluted shares and earnings per average common shares 214.2 $0.58 212.2 $3.31 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,448,982 options for the three months ended June 30, 2024 and 1,315,567 options for the three months ended June 30, 2023. The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was 1,471,220 options for the six months ended June 30, 2024 and 1,248,743 options for the six months ended June 30, 2023. |
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 three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, ($166,128) ($189,727) Amounts reclassified from accumulated other comprehensive income (loss) 246,489 (3,292) Net other comprehensive income (loss) for the period 246,489 (3,292) Ending balance, June 30, $80,361 ($193,019) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, ($162,460) ($191,754) Amounts reclassified from accumulated other comprehensive income (loss) 242,821 (1,265) Net other comprehensive income (loss) for the period 242,821 (1,265) Ending balance, June 30, $80,361 ($193,019) |
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block] | Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $3,473 $3,398 (a) Amortization of net gain 1,641 1,633 (a) Settlement loss (316,974) (674) (a) Total amortization and settlement loss (311,860) 4,357 Income taxes 65,371 (1,065) Income taxes Total amortization and settlement loss (net of tax) ($246,489) $3,292 Total reclassifications for the period (net of tax) ($246,489) $3,292 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $6,946 $6,795 (a) Amortization of net gain 3,037 3,295 (a) Settlement loss (316,974) (8,490) (a) Total amortization and settlement loss (306,991) 1,600 Income taxes 64,170 (335) Income taxes Total amortization and settlement loss (net of tax) ($242,821) $1,265 Total reclassifications for the period (net of tax) ($242,821) $1,265 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein 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 for Entergy Louisiana for the three months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, April 1, $52,774 $54,584 Amounts reclassified from accumulated other comprehensive income (2,023) (1,773) Net other comprehensive loss for the period (2,023) (1,773) Ending balance, June 30, $50,751 $52,811 The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2024 and 2023: Pension and Other Postretirement Benefit Plans 2024 2023 (In Thousands) Beginning balance, January 1, $54,798 $55,370 Amounts reclassified from accumulated other comprehensive income (4,047) (2,559) Net other comprehensive loss for the period (4,047) (2,559) Ending balance, June 30, $50,751 $52,811 |
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block] | Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $1,136 $951 (a) Amortization of net gain 1,632 1,564 (a) Settlement loss — (89) (a) Total amortization and settlement loss 2,768 2,426 Income taxes (745) (653) Income taxes Total amortization and settlement loss (net of tax) 2,023 1,773 Total reclassifications for the period (net of tax) $2,023 $1,773 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2024 and 2023 are as follows: Amounts reclassified Income Statement Location 2024 2023 (In Thousands) Pension and other postretirement benefit plans Amortization of prior service credit $2,272 $1,902 (a) Amortization of net gain 3,266 3,129 (a) Settlement loss — (1,529) (a) Total amortization and settlement loss 5,538 3,502 Income taxes (1,491) (943) Income taxes Total amortization and settlement loss (net of tax) 4,047 2,559 Total reclassifications for the period (net of tax) $4,047 $2,559 (a) These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. |
Revolving Credit Facilities, _2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Schedule of Line of Credit Facilities [Table Text Block] | The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2024: Capacity Borrowings Letters Capacity (In Millions) $3,000 $— $4 $2,996 |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Schedule of uncommitted standby letter of credit facilities [Table Text Block] | The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of nuclear fuel company VIE credit facilities [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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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. |
Schedule of nuclear fuel company VIE 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Schedule of uncommitted standby letter of credit facilities [Table Text Block] | The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of nuclear fuel company VIE credit facilities [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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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. |
Schedule of nuclear fuel company VIE 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Schedule of uncommitted standby letter of credit facilities [Table Text Block] | The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Schedule of uncommitted standby letter of credit facilities [Table Text Block] | The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 as follows: Company Expiration Amount of Interest Rate Amount Drawn Letters of Credit Entergy Arkansas April 2026 $25 million (b) 7.29% $— $— Entergy Arkansas June 2029 $300 million (c) 6.57% $— $— Entergy Louisiana June 2029 $400 million (c) 6.69% $— $— Entergy Mississippi June 2029 $300 million (c) 6.57% $— $— Entergy New Orleans June 2027 $25 million (c) 7.07% $— $— Entergy Texas June 2029 $300 million (c) 6.69% $— $1.1 million (a) The interest rate is the estimated interest rate as of June 30, 2024 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; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. |
Schedule of uncommitted standby letter of credit facilities [Table Text Block] | The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2024: Company Amount of Letter of Credit Fee Letters of Credit Entergy Arkansas $25 million 0.78% $12.4 million Entergy Louisiana $125 million 0.78% $20.7 million Entergy Mississippi $65 million 0.78% $41.1 million Entergy New Orleans $15 million 1.625% $0.5 million Entergy Texas $80 million 1.250% $79.7 million (a) As of June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2024, the letters of credit issued for Entergy Mississippi include $30.9 million in MISO letters of credit and $10.2 million in non-MISO letters 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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
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 June 30, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $200 $40 Entergy New Orleans $150 $— Entergy Texas $200 $— System Energy $200 $— |
Schedule of nuclear fuel company VIE credit facilities [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 June 30, 2024: Company Expiration Amount Weighted- Amount (Dollars in Millions) Entergy Arkansas VIE June 2027 $80 6.44% $— Entergy Louisiana River Bend VIE June 2027 $105 6.43% $27.9 Entergy Louisiana Waterford VIE June 2027 $105 6.43% $26.5 System Energy VIE June 2027 $120 6.43% $104.1 (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. |
Schedule of nuclear fuel company VIE 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 June 30, 2024 as follows: Company Description Amount Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Arkansas VIE 5.54% Series O due May 2029 $70 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 |
Schedule of Long-Term Debt Instruments [Table Text Block] | The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2024 were as follows: Book Value Fair Value (In Thousands) Entergy $27,818,164 $24,689,579 Entergy Arkansas $5,094,160 $4,470,941 Entergy Louisiana $10,188,393 $8,964,781 Entergy Mississippi $2,426,614 $2,093,565 Entergy New Orleans $736,476 $695,029 Entergy Texas $3,216,909 $2,823,011 System Energy $822,762 $782,228 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2023 were as follows: Book Value Fair Value (In Thousands) Entergy $25,107,896 $22,489,174 Entergy Arkansas $4,673,080 $4,166,941 Entergy Louisiana $9,420,689 $8,414,512 Entergy Mississippi $2,229,510 $1,969,334 Entergy New Orleans $677,450 $602,716 Entergy Texas $3,225,092 $2,936,130 System Energy $738,459 $696,168 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. |
Stock-Based Compensation (Table
Stock-Based Compensation (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Employee Stock Option | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for stock options for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $1.1 $1.1 Tax benefit recognized in Entergy’s consolidated net income $0.3 $0.3 Compensation cost capitalized as part of fixed assets and materials and supplies $0.5 $0.6 The following table includes financial information for stock options for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $2.2 $2.1 Tax benefit recognized in Entergy’s consolidated net income $0.6 $0.6 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0 $1.1 |
Other Equity Awards [Member] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Line Items] | |
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block] | The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $9.8 $10.1 Tax benefit recognized in Entergy’s consolidated net income $2.5 $2.6 Compensation cost capitalized as part of fixed assets and materials and supplies $4.6 $4.4 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Compensation expense included in Entergy’s consolidated net income $19.7 $17.8 Tax benefit recognized in Entergy’s consolidated net income $5.0 $4.6 Compensation cost capitalized as part of fixed assets and materials and supplies $9.1 $7.6 |
Retirement And Other Postreti_2
Retirement And Other Postretirement Benefits (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $23,370 $25,366 Interest cost on projected benefit obligation 65,961 74,033 Expected return on assets (89,506) (95,752) Recognized net loss 14,854 21,307 Settlement charges 325,253 7,246 Net pension costs $339,932 $32,200 Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $46,746 $51,044 Interest cost on projected benefit obligation 136,587 149,734 Expected return on assets (185,486) (193,885) Recognized net loss 29,974 43,654 Settlement charges 325,253 145,674 Net pension cost $353,074 $196,221 |
Schedule of reclassifications out of accumulated other comprehensive income [Table Text Block] | Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 |
Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $3,126 $3,664 Interest cost on accumulated postretirement benefit obligation (APBO) 9,852 10,568 Expected return on assets (10,569) (9,183) Amortization of prior service credit (5,720) (5,640) Recognized net gain (2,761) (2,862) Net other postretirement benefits income ($6,072) ($3,453) Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2024 and 2023, included the following components: 2024 2023 (In Thousands) Service cost - benefits earned during the period $6,252 $7,328 Interest cost on accumulated postretirement benefit obligation (APBO) 19,704 21,136 Expected return on assets (21,138) (18,366) Amortization of prior service credit (11,440) (11,280) Recognized net gain (5,522) (5,724) Net other postretirement benefits income ($12,144) ($6,906) |
Entergy Arkansas [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 |
Entergy Louisiana [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of reclassifications out of accumulated other comprehensive income [Table Text Block] | Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,513 ($40) $3,473 Amortization of net gain (loss) (894) 2,615 (80) 1,641 Settlement loss (316,974) — — (316,974) ($317,868) $6,128 ($120) ($311,860) Entergy Louisiana Amortization of prior service credit $— $1,136 $— $1,136 Amortization of net gain (loss) (104) 1,738 (2) 1,632 ($104) $2,874 ($2) $2,768 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $3,510 ($112) $3,398 Amortization of net gain (loss) (1,104) 2,897 (160) 1,633 Settlement loss (310) — (364) (674) ($1,414) $6,407 ($636) $4,357 Entergy Louisiana Amortization of prior service credit $— $951 $— $951 Amortization of net gain (loss) (200) 1,764 — 1,564 Settlement loss (89) — — (89) ($289) $2,715 $— $2,426 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2024 and 2023: 2024 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,026 ($80) $6,946 Amortization of net gain (loss) (2,033) 5,230 (160) 3,037 Settlement loss (316,974) — — (316,974) ($319,007) $12,256 ($240) ($306,991) Entergy Louisiana Amortization of prior service credit $— $2,272 $— $2,272 Amortization of net gain (loss) (208) 3,476 (2) 3,266 ($208) $5,748 ($2) $5,538 2023 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service credit (cost) $— $7,020 ($225) $6,795 Amortization of net gain (loss) (2,144) 5,796 (357) 3,295 Settlement loss (6,957) — (1,533) (8,490) ($9,101) $12,816 ($2,115) $1,600 Entergy Louisiana Amortization of prior service credit $— $1,902 $— $1,902 Amortization of net gain (loss) (398) 3,528 (1) 3,129 Settlement loss (1,529) — — (1,529) ($1,927) $5,430 ($1) $3,502 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 |
Entergy Mississippi [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 |
Entergy New Orleans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 |
Entergy Texas [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Entergy Texas [Member] | Non Qualified Pension Plans [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the second quarters of 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $68 $51 $83 $31 $62 2023 $63 $25 $87 $33 $63 The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2024 and 2023: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2024 $136 $102 $166 $61 $124 2023 $513 $52 $639 $66 $126 |
System Energy [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,100 $5,551 $1,284 $440 $962 $1,383 Interest cost on projected benefit obligation 13,217 13,961 3,521 1,569 2,831 3,386 Expected return on assets (18,155) (19,447) (5,113) (2,203) (4,077) (4,633) Recognized net loss 5,746 2,602 1,140 470 393 1,162 Settlement charges — — — — — 611 Net pension cost $4,908 $2,667 $832 $276 $109 $1,909 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $4,661 $6,199 $1,456 $487 $1,090 $1,445 Interest cost on projected benefit obligation 13,917 14,944 3,824 1,669 3,162 3,435 Expected return on assets (17,878) (18,766) (4,635) (2,310) (4,023) (4,501) Recognized net loss 5,763 4,992 1,627 484 1,059 1,274 Settlement charges 1,784 2,232 88 7 592 490 Net pension cost $8,247 $9,601 $2,360 $337 $1,880 $2,143 The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $8,199 $11,102 $2,568 $880 $1,923 $2,767 Interest cost on projected benefit obligation 26,434 27,922 7,042 3,138 5,662 6,777 Expected return on assets (36,310) (38,894) (10,226) (4,407) (8,154) (9,281) Recognized net loss 11,492 5,204 2,280 940 786 2,327 Settlement charges — — — — — 611 Net pension cost $9,815 $5,334 $1,664 $551 $217 $3,201 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $9,410 $12,479 $2,938 $978 $2,197 $2,912 Interest cost on projected benefit obligation 28,197 30,323 7,754 3,384 6,404 6,963 Expected return on assets (35,954) (37,999) (9,519) (4,577) (8,175) (9,039) Recognized net loss 12,732 9,956 3,392 997 2,049 2,735 Settlement charges 23,958 38,230 11,743 1,700 10,270 5,290 Net pension cost $38,343 $52,989 $16,308 $2,482 $12,745 $8,861 |
Schedule of Expected Benefit Payments [Table Text Block] | Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2024: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2024 pension contributions $55,112 $48,401 $14,980 $4,931 $8,272 $16,650 Pension contributions made through June 2024 $22,784 $19,862 $7,240 $1,499 $3,037 $6,666 Remaining estimated pension contributions to be made in 2024 $32,328 $28,539 $7,740 $3,432 $5,235 $9,984 |
System Energy [Member] | Other Postretirement Benefits Plan [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the second quarters of 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $642 $700 $184 $51 $168 $175 Interest cost on APBO 1,833 1,999 486 253 603 398 Expected return on assets (4,384) — (1,372) (1,479) (2,539) (728) Amortization of prior service cost (credit) 524 (1,136) (239) (229) (1,093) (73) Recognized net (gain) loss — (1,738) 15 19 148 — Net other postretirement benefits income ($1,385) ($175) ($926) ($1,385) ($2,713) ($228) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $741 $845 $220 $59 $202 $189 Interest cost on APBO 2,001 2,233 543 290 649 432 Expected return on assets (3,778) — (1,179) (1,316) (2,194) (634) Amortization of prior service cost (credit) 524 (951) (239) (229) (1,093) (73) Recognized net (gain) loss 43 (1,764) 21 117 229 — Net other postretirement benefits (income) cost ($469) $363 ($634) ($1,079) ($2,207) ($86) The Registrant Subsidiaries’ other postretirement benefits cost (income), including amounts capitalized, for their current and former employees for the six months ended June 30, 2024 and 2023, included the following components: 2024 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,284 $1,400 $368 $102 $336 $350 Interest cost on APBO 3,666 3,998 972 506 1,206 796 Expected return on assets (8,768) — (2,744) (2,958) (5,078) (1,456) Amortization of prior service cost (credit) 1,048 (2,272) (478) (458) (2,186) (146) Recognized net (gain) loss — (3,476) 30 38 296 — Net other postretirement benefits income ($2,770) ($350) ($1,852) ($2,770) ($5,426) ($456) 2023 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,482 $1,690 $440 $118 $404 $378 Interest cost on APBO 4,002 4,466 1,086 580 1,298 864 Expected return on assets (7,556) — (2,358) (2,632) (4,388) (1,268) Amortization of prior service cost (credit) 1,048 (1,902) (478) (458) (2,186) (146) Recognized net (gain) loss 86 (3,528) 42 234 458 — Net other postretirement benefits (income) cost ($938) $726 ($1,268) ($2,158) ($4,414) ($172) |
Business Segment Information (T
Business Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Entergy Corporation [Member] | |
Schedule of Segment Reporting Information, by Segment [Table Text Block] | Entergy’s segment financial information for the second quarters of 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $2,941,404 $12,227 ($11) $2,953,620 Income taxes $113,017 ($79,383) $— $33,634 Consolidated net income (loss) $443,319 ($312,702) ($78,885) $51,732 2023 Operating revenues $2,818,747 $27,287 ($8) $2,846,026 Income taxes $144,489 ($9,693) $— $134,796 Consolidated net income (loss) $514,498 ($40,559) ($81,925) $392,014 Entergy’s segment financial information for the six months ended June 30, 2024 and 2023 was as follows: Utility Parent & Other Eliminations Consolidated (In Thousands) 2024 Operating revenues $5,713,577 $34,703 ($32) $5,748,248 Income taxes $147,565 ($92,938) $— $54,627 Consolidated net income (loss) $639,299 ($352,585) ($158,446) $128,268 Total assets as of June 30, 2024 $66,945,968 $925,848 ($5,105,519) $62,766,297 2023 Operating revenues $5,766,738 $60,358 ($11) $5,827,085 Income taxes $78,363 ($22,542) $— $55,821 Consolidated net income (loss) $912,664 ($70,953) ($137,399) $704,312 Total assets as of December 31, 2023 $63,887,038 $836,598 ($5,020,240) $59,703,396 Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment. |
Risk Management And Fair Valu_2
Risk Management And Fair Values (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
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 June 30, 2024 and December 31, 2023 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) 2024 Assets: Financial transmission rights Prepayments and other $49 $— $ 49 Liabilities: Natural gas swaps and options Other current liabilities $2 $— $ 2 2023 Assets: Financial transmission rights Prepayments and other $21 $— $ 21 Liabilities: Natural gas swaps and options Other current liabilities $11 $— $ 11 (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 letters of credit in the amount of $3 million posted as of June 30, 2024 and $2 million posted as of December 31, 2023 |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $ 3 Financial transmission rights Purchased power expense (b) $ 47 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($1) Financial transmission rights Purchased power expense (b) $ 32 The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2024 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $ 100 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) ($38) Financial transmission rights Purchased power expense (b) $ 48 (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] | 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 June 30, 2024 and December 31, 2023. 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. 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,272 $— $— $1,272 Decommissioning trust funds (a): Equity securities 54 — — 54 Debt securities 721 1,201 — 1,922 Common trusts (b) 3,289 Securitization recovery trust account 4 — — 4 Storm reserve escrow accounts 333 — — 333 Financial transmission rights — — 49 49 $2,384 $1,201 $49 $6,923 Liabilities: Gas hedge contracts $2 $— $— $2 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 (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 9 to the financial statements herein 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. |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of April 1, $9 $7 Total gains (losses) for the period Included as a regulatory liability/asset 34 23 Issuances of financial transmission rights 53 42 Settlements (47) (32) Balance as of June 30, $49 $40 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024 and 2023: 2024 2023 (In Millions) Balance as of January 1, $21 $19 Total gains (losses) for the period Included as a regulatory liability/asset 75 27 Issuances of financial transmission rights 53 42 Settlements (100) (48) Balance as of June 30, $49 $40 |
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 June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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] | The following tables set 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 June 30, 2024 and December 31, 2023. 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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $772.2 $— $— $772.2 Decommissioning trust funds (a): Equity securities 33.1 — — 33.1 Debt securities 165.1 389.3 — 554.4 Common trusts (b) 935.0 Financial transmission rights — — 16.1 16.1 $970.4 $389.3 $16.1 $2,310.8 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 |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $185.3 $— $— $185.3 Decommissioning trust funds (a): Equity securities 18.6 — — 18.6 Debt securities 293.7 518.9 — 812.6 Common trusts (b) 1,461.0 Storm reserve escrow account 250.4 — — 250.4 Financial transmission rights — — 19.8 19.8 $748.0 $518.9 $19.8 $2,747.7 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 |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $3.1 $— $— $3.1 Storm reserve escrow account 0.8 — — 0.8 Financial transmission rights — — 3.6 3.6 $3.9 $— $3.6 $7.5 Liabilities: Gas hedge contracts $1.5 $— $— $1.5 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 |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $6.5 $— $— $6.5 Securitization recovery trust account 1.3 — — 1.3 Storm reserve escrow account 81.7 — — 81.7 Financial transmission rights — — 2.6 2.6 $89.5 $— $2.6 $92.1 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 |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
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 June 30, 2024 and December 31, 2023 are shown in the tables 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) 2024 Assets: Financial transmission rights Prepayments and other $16.1 $— $ 16.1 Entergy Arkansas Financial transmission rights Prepayments and other $19.9 ($0.1) $ 19.8 Entergy Louisiana Financial transmission rights Prepayments and other $3.6 $— $ 3.6 Entergy Mississippi Financial transmission rights Prepayments and other $2.6 $— $ 2.6 Entergy New Orleans Financial transmission rights Prepayments and other $6.6 $— $ 6.6 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $1.5 $— $ 1.5 Entergy Mississippi 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 (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 June 30, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $1.0 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.4 million for Entergy Texas. 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. |
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 three months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($3.0) (a) Entergy Mississippi Financial transmission rights Purchased power expense $ 12.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 25.0 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 2.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 3.3 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.6 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $ 0.8 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($1.2) (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 $ 4.1 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 19.5 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.0 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 1.5 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 3.5 (b) Entergy Texas The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2024 and 2023 are as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2024 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 2.3 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 0.5 (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 38.9 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 41.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 3.1 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 4.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 12.1 (b) Entergy Texas 2023 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.7) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $ 29.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.1) (a) Entergy New Orleans Financial transmission rights Purchased power expense $ 8.0 (b) Entergy Arkansas Financial transmission rights Purchased power expense $ 28.3 (b) Entergy Louisiana Financial transmission rights Purchased power expense $ 4.5 (b) Entergy Mississippi Financial transmission rights Purchased power expense $ 2.4 (b) Entergy New Orleans Financial transmission rights Purchased power expense $ 4.2 (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 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $124.9 $— $— $124.9 Securitization recovery trust account 2.3 — — 2.3 Financial transmission rights — — 6.6 6.6 $127.2 $— $6.6 $133.8 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 |
Schedule of 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 financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $2.8 $4.1 $0.6 $0.5 $1.2 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 7.7 19.1 1.2 2.6 2.7 Settlements (12.0) (25.0) (2.1) (3.3) (4.6) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $4.0 $2.5 $0.2 $0.3 ($0.1) Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (0.9) 15.6 2.6 1.3 4.6 Settlements (4.1) (19.5) (3.0) (1.5) (3.5) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $6.0 $9.8 $1.4 $1.1 $2.4 Issuances of financial transmission rights 17.6 21.6 3.9 2.8 7.3 Gains (losses) included as a regulatory liability/asset 31.4 29.6 1.4 3.1 9.0 Settlements (38.9) (41.2) (3.1) (4.4) (12.1) Balance as of June 30, $16.1 $19.8 $3.6 $2.6 $6.6 The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2023. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $10.3 $7.3 $0.6 $0.8 $0.1 Issuances of financial transmission rights 20.6 18.1 1.4 1.4 0.2 Gains (losses) included as a regulatory liability/asset (3.3) 19.6 3.7 1.7 5.1 Settlements (8.0) (28.3) (4.5) (2.4) (4.2) Balance as of June 30, $19.6 $16.7 $1.2 $1.5 $1.2 |
System Energy [Member] | |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | System Energy 2024 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $30.8 $— $— $30.8 Decommissioning trust funds (a): Equity securities 2.0 — — 2.0 Debt securities 262.3 292.3 — 554.6 Common trusts (b) 893.7 $295.1 $292.3 $— $1,481.1 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 |
Decommissioning Trust Funds (Ta
Decommissioning Trust Funds (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $1,922 $10 $139 2023 Debt Securities $1,770 $19 $134 |
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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $453 $5 $134 $6 More than 12 months 949 134 999 128 Total $1,402 $139 $1,133 $134 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $76 $82 1 year - 5 years 568 517 5 years - 10 years 575 504 10 years - 15 years 120 121 15 years - 20 years 186 179 20 years+ 397 367 Total $1,922 $1,770 |
Entergy Arkansas [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.4 $1.9 $59.0 2023 Debt Securities $496.9 $2.4 $53.6 |
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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $70.8 $1.1 $22.5 $0.4 More than 12 months 388.7 57.9 403.4 53.2 Total $459.5 $59.0 $425.9 $53.6 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $43.5 $45.3 1 year - 5 years 156.3 132.2 5 years - 10 years 234.8 205.7 10 years - 15 years 31.7 39.9 15 years - 20 years 59.8 49.6 20 years+ 28.3 24.2 Total $554.4 $496.9 |
Entergy Louisiana [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $812.6 $4.6 $39.8 2023 Debt Securities $788.1 $11.7 $37.4 |
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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $275.6 $2.7 $69.8 $0.9 More than 12 months 340.4 37.1 356.1 36.5 Total $616.0 $39.8 $425.9 $37.4 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $27.3 $31.4 1 year - 5 years 189.2 181.6 5 years - 10 years 186.9 170.0 10 years - 15 years 79.8 70.2 15 years - 20 years 84.7 90.2 20 years+ 244.7 244.7 Total $812.6 $788.1 |
System Energy [Member] | |
Schedule of Available-for-Sale Securities Reconciliation [Table Text Block] | The available-for-sale securities held as of June 30, 2024 and December 31, 2023 are summarized as follows: Fair Total Total (In Millions) 2024 Debt Securities $554.6 $3.2 $40.2 2023 Debt Securities $485.2 $4.5 $42.5 |
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 June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 Fair Gross Fair Gross (In Millions) Less than 12 months $106.8 $1.6 $42.1 $4.5 More than 12 months 219.8 38.6 239.1 38.0 Total $326.6 $40.2 $281.2 $42.5 |
Investments Classified by Contractual Maturity Date [Table Text Block] | The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2024 and December 31, 2023 were as follows: 2024 2023 (In Millions) Less than 1 year $5.4 $5.3 1 year - 5 years 222.1 203.4 5 years - 10 years 153.5 128.6 10 years - 15 years 8.1 10.7 15 years - 20 years 41.0 38.8 20 years+ 124.5 98.4 Total $554.6 $485.2 |
Revenue Recognition (Tables)
Revenue Recognition (Tables) | 6 Months Ended |
Jun. 30, 2024 | |
Disaggregation of Revenue [Table Text Block] | Entergy’s total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $1,009,836 $951,424 Commercial 713,282 692,788 Industrial 792,721 750,177 Governmental 65,861 63,816 Total billed retail 2,581,700 2,458,205 Sales for resale (a) 54,579 68,262 Other electric revenues (b) 257,813 247,331 Revenues from contracts with customers 2,894,092 2,773,798 Other Utility revenues (c) 11,955 11,446 Electric revenues 2,906,047 2,785,244 Natural gas revenues 35,357 33,503 Other revenues (d) 12,216 27,279 Total operating revenues $2,953,620 $2,846,026 Entergy’s total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 2023 (In Thousands) Utility: Residential $2,080,177 $1,992,883 Commercial 1,405,133 1,407,089 Industrial 1,541,679 1,613,899 Governmental 131,172 131,153 Total billed retail 5,158,161 5,145,024 Sales for resale (a) 133,583 176,209 Other electric revenues (b) 293,847 291,788 Revenues from contracts with customers 5,585,591 5,613,021 Other Utility revenues (c) 26,962 55,633 Electric revenues 5,612,553 5,668,654 Natural gas revenues 101,024 98,084 Other revenues (d) 34,671 60,347 Total operating revenues $5,748,248 $5,827,085 |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Entergy Arkansas [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Entergy Louisiana [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Entergy Mississippi [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Entergy New Orleans [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Entergy Texas [Member] | |
Disaggregation of Revenue [Table Text Block] | The Utility operating companies’ total revenues for the three months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,822 $353,975 $163,049 $71,842 $216,148 Commercial 132,950 265,869 142,173 57,360 114,930 Industrial 138,786 458,420 49,180 7,602 138,733 Governmental 4,433 21,223 14,061 19,167 6,977 Total billed retail 480,991 1,099,487 368,463 155,971 476,788 Sales for resale (a) 43,842 80,823 21,260 8,575 3,015 Other electric revenues (b) 81,733 74,670 50,718 12,811 39,224 Revenues from contracts with customers 606,566 1,254,980 440,441 177,357 519,027 Other revenues (c) 2,232 6,464 2,453 1,307 50 Electric revenues 608,798 1,261,444 442,894 178,664 519,077 Natural gas revenues — 14,680 — 20,677 — Total operating revenues $608,798 $1,276,124 $442,894 $199,341 $519,077 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $204,808 $334,246 $163,001 $68,535 $180,834 Commercial 136,591 253,365 142,997 56,095 103,740 Industrial 153,817 407,045 54,738 7,562 127,015 Governmental 4,945 19,407 14,971 17,896 6,597 Total billed retail 500,161 1,014,063 375,707 150,088 418,186 Sales for resale (a) 48,266 80,248 26,073 11,075 1,986 Other electric revenues (b) 65,807 91,372 40,966 5,667 44,861 Revenues from contracts with customers 614,234 1,185,683 442,746 166,830 465,033 Other revenues (c) 2,113 6,226 2,384 1,386 (603) Electric revenues 616,347 1,191,909 445,130 168,216 464,430 Natural gas revenues — 13,703 — 19,800 — Total operating revenues $616,347 $1,205,612 $445,130 $188,016 $464,430 The Utility operating companies’ total revenues for the six months ended June 30, 2024 and 2023 were as follows: 2024 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $480,574 $699,003 $341,666 $139,520 $419,414 Commercial 274,258 522,565 274,491 110,585 223,234 Industrial 288,193 880,017 95,607 14,580 263,282 Governmental 9,133 43,044 27,390 37,521 14,084 Total billed retail 1,052,158 2,144,629 739,154 302,206 920,014 Sales for resale (a) 82,807 163,551 69,193 21,075 4,922 Other electric revenues (b) 91,074 112,615 44,516 9,592 38,736 Revenues from contracts with customers 1,226,039 2,420,795 852,863 332,873 963,672 Other revenues (c) 4,804 13,442 4,887 2,732 (104) Electric revenues 1,230,843 2,434,237 857,750 335,605 963,568 Natural gas revenues — 44,327 — 56,697 — Total operating revenues $1,230,843 $2,478,564 $857,750 $392,302 $963,568 2023 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $444,307 $694,892 $332,390 $132,101 $389,193 Commercial 261,927 531,543 276,673 110,164 226,782 Industrial 285,053 916,949 106,153 14,975 290,769 Governmental 9,605 42,481 28,854 35,694 14,519 Total billed retail 1,000,892 2,185,865 744,070 292,934 921,263 Sales for resale (a) 114,283 163,484 64,816 35,985 4,431 Other electric revenues (b) 79,524 117,939 43,840 6,084 47,085 Revenues from contracts with customers 1,194,699 2,467,288 852,726 335,003 972,779 Other revenues (c) 4,397 44,373 4,832 2,908 (843) Electric revenues 1,199,096 2,511,661 857,558 337,911 971,936 Natural gas revenues — 39,159 — 58,925 — Total operating revenues $1,199,096 $2,550,820 $857,558 $396,836 $971,936 (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 and unbilled revenue. (c) Other Utility revenues include the equity component of carrying costs related to securitization, 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, and operation and management services fees. |
Allowance for Doubtful Accounts [Table Text Block] | The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2024 and 2023. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2023 $25.9 $7.2 $6.1 $3.3 $7.8 $1.5 Provisions 15.3 2.6 6.2 2.2 1.4 2.9 Write-offs (46.0) (10.7) (15.6) (7.4) (7.1) (5.2) Recoveries 21.4 5.2 6.7 4.1 3.7 1.7 Balance as of June 30, 2024 $16.6 $4.3 $3.4 $2.2 $5.8 $0.9 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 15.5 3.2 7.0 2.1 0.7 2.5 Write-offs (51.5) (13.2) (21.4) (3.7) (6.5) (6.7) Recoveries 26.9 8.7 11.7 1.5 1.5 3.5 Balance as of June 30, 2023 $21.8 $5.2 $4.9 $2.4 $7.6 $1.7 |
Rate And Regulatory Matters (Na
Rate And Regulatory Matters (Narrative - All Other) (Details) | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | |||||||||||||||
Aug. 31, 2024 USD ($) | Jul. 31, 2024 USD ($) | Jun. 30, 2024 USD ($) kWh | Apr. 30, 2024 USD ($) | Mar. 31, 2024 USD ($) | Feb. 29, 2024 USD ($) | Dec. 31, 2023 USD ($) | Jul. 31, 2020 USD ($) | Dec. 31, 2018 USD ($) | Jun. 30, 2024 USD ($) | Mar. 31, 2024 USD ($) | Jun. 30, 2023 USD ($) | Dec. 31, 2024 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Dec. 31, 2025 USD ($) | Mar. 31, 2025 USD ($) | Mar. 31, 2024 USD ($) | Dec. 31, 2023 USD ($) | |
Regulatory Liability, Noncurrent | $ 3,488,314,000 | $ 3,116,926,000 | $ 3,488,314,000 | $ 3,488,314,000 | $ 3,116,926,000 | ||||||||||||||
Regulatory Asset, Noncurrent | 5,408,682,000 | 5,669,404,000 | 5,408,682,000 | 5,408,682,000 | 5,669,404,000 | ||||||||||||||
Asset Impairment Charges | 0 | $ 0 | 131,775,000 | $ 0 | |||||||||||||||
Entergy Arkansas [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | 803,680,000 | 759,181,000 | 803,680,000 | 803,680,000 | 759,181,000 | ||||||||||||||
Regulatory Asset, Noncurrent | 1,705,642,000 | 1,885,361,000 | 1,705,642,000 | 1,705,642,000 | 1,885,361,000 | ||||||||||||||
Payments for Legal Settlements | $ 135,000,000 | ||||||||||||||||||
Refund to customers, plus interest, associated with recalculated bandwidth remedy | $ 13,700,000 | ||||||||||||||||||
Asset Impairment Charges | 0 | $ 0 | 131,775,000 | $ 0 | |||||||||||||||
Entergy Arkansas [Member] | Opportunity Sales [Member] | |||||||||||||||||||
Regulatory Asset, Noncurrent | 131,800,000 | 131,800,000 | |||||||||||||||||
Asset Impairment Charges | $ 131,800,000 | ||||||||||||||||||
Asset Impairment Charges, net of tax | 99,100,000 | ||||||||||||||||||
Entergy Louisiana [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | 1,692,861,000 | 1,407,689,000 | 1,692,861,000 | 1,692,861,000 | 1,407,689,000 | ||||||||||||||
Regulatory Asset, Noncurrent | 1,657,857,000 | 1,648,852,000 | 1,657,857,000 | 1,657,857,000 | 1,648,852,000 | ||||||||||||||
Entergy Mississippi [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 5,200,000 | ||||||||||||||||||
Regulatory Liability, Noncurrent | 35,912,000 | 33,696,000 | 35,912,000 | 35,912,000 | 33,696,000 | ||||||||||||||
Regulatory Asset, Noncurrent | 573,751,000 | 579,076,000 | 573,751,000 | 573,751,000 | 579,076,000 | ||||||||||||||
Monthly storm damage provision | $ 1,750,000 | ||||||||||||||||||
Storm Damage Provision Balance | 70,000,000 | 15,000,000 | 15,000,000 | 70,000,000 | $ 70,000,000 | 15,000,000 | |||||||||||||
Storm damage provision balance at which collections will resume | 60,000,000 | 10,000,000 | |||||||||||||||||
Disbursement from storm reserve rescrow | 34,500,000 | ||||||||||||||||||
Entergy New Orleans [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | 259,613,000 | 90,434,000 | 259,613,000 | 259,613,000 | 90,434,000 | ||||||||||||||
Regulatory Asset, Noncurrent | 171,294,000 | 182,367,000 | 171,294,000 | 171,294,000 | 182,367,000 | ||||||||||||||
Entergy New Orleans [Member] | Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | $ 138,000,000 | 138,000,000 | 60,000,000 | 138,000,000 | 138,000,000 | 60,000,000 | |||||||||||||
Entergy Texas [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | 27,938,000 | 43,013,000 | 27,938,000 | 27,938,000 | 43,013,000 | ||||||||||||||
Regulatory Asset, Noncurrent | $ 556,409,000 | 596,606,000 | 556,409,000 | 556,409,000 | $ 596,606,000 | ||||||||||||||
Energy Cost Recovery Rider [Member] | Entergy Arkansas [Member] | |||||||||||||||||||
Energy Cost Recovery Rider Rate Per kWh | 0.00882 | 0.01883 | |||||||||||||||||
Credit for recovery attributed to net metering costs | 9,000,000 | ||||||||||||||||||
Adjustment to over-recovery balance | $ 43,700,000 | $ 43,700,000 | $ 43,700,000 | ||||||||||||||||
Energy Cost Recovery Rider [Member] | Entergy Arkansas [Member] | Subsequent Event [Member] | |||||||||||||||||||
Requested Energy Cost Recovery Rider Rate Per kWh | $ 0.00882 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | |||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 7.48% | ||||||||||||||||||
Projected Revenue Deficiency | $ 33,100,000 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | Subsequent Event [Member] | |||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 8.43% | ||||||||||||||||||
Projected Revenue Deficiency | $ 69,500,000 | ||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 102,600,000 | ||||||||||||||||||
Annual revenue constraint per rate class percentage | 4% | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Arkansas [Member] | Subsequent Event [Member] | Maximum [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 82,600,000 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | |||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 7.10% | ||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 63,400,000 | ||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 32,600,000 | $ 0 | |||||||||||||||||
Annual depreciation expense increase | $ 55,200,000 | ||||||||||||||||||
Earned return on rate base | 6.08% | 6.81% | |||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 64,600,000 | $ 300,000 | |||||||||||||||||
Regulatory Asset, Noncurrent | 7,300,000 | 7,300,000 | $ 7,300,000 | ||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | Residential [Member] | |||||||||||||||||||
Customer charge | $ 31.82 | ||||||||||||||||||
Average customer usage | kWh | 1,000 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | General service | |||||||||||||||||||
Customer charge | $ 53.10 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | Maximum [Member] | |||||||||||||||||||
Cap on retail revenues in look-back filing | 0.02 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy Mississippi [Member] | Subsequent Event [Member] | |||||||||||||||||||
Public Utilities, Interim Rate Increase (Decrease), Amount | $ 8,700,000 | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 12,600,000 | ||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.35% | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | Electricity [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 7,000,000 | ||||||||||||||||||
Earned return on equity | 8.66% | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | Natural Gas, US Regulated [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 5,600,000 | ||||||||||||||||||
Earned return on equity | 5.87% | ||||||||||||||||||
2024 Formula Rate Plan Filing [Member] | Entergy New Orleans [Member] | Subsequent Event [Member] | |||||||||||||||||||
Requested reduction to formula rate plan revenues resulting from alleged errors | $ 1,600,000 | ||||||||||||||||||
Grand Gulf Credit Rider [Member] | Entergy Arkansas [Member] | Subsequent Event [Member] | |||||||||||||||||||
Refund to retail customers | $ 100,600,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | |||||||||||||||||||
Expenses reflecting effects of agreement in principle | 151,000,000 | ||||||||||||||||||
Expenses reflecting effects of agreement in principle, net of tax | $ 111,000,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit [Member] | |||||||||||||||||||
Regulatory Liability, Noncurrent | $ 38,000,000 | $ 38,000,000 | |||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | |||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.70% | ||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 120,000,000 | ||||||||||||||||||
Customer rate credits | $ 184,000,000 | ||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.50% | ||||||||||||||||||
Basis points bandwidth above and below midpoint return on common equity | 40 | ||||||||||||||||||
Increase in nuclear depreciation rates | $ 15,000,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | System Energy Settlement with the LPSC | |||||||||||||||||||
Customer rate credits | 75,800,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | Formula Rate Plan Global Settlement | |||||||||||||||||||
Customer rate credits | 5,800,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 140,000,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member] | 2023 | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 350,000,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member] | 2024 | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 375,000,000 | ||||||||||||||||||
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member] | 2025 | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 400,000,000 | ||||||||||||||||||
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member] | |||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 40,300,000 |
Rate And Regulatory Matters (_2
Rate And Regulatory Matters (Narrative - Complaints Against System Energy) (Details) - USD ($) $ in Thousands | 1 Months Ended | 6 Months Ended | ||||||||||||||||||
Nov. 01, 2023 | Sep. 30, 2024 | Jul. 31, 2024 | Jun. 30, 2024 | May 31, 2024 | Apr. 30, 2024 | Oct. 31, 2023 | May 31, 2023 | Jan. 31, 2023 | Dec. 31, 2022 | Nov. 30, 2022 | Oct. 31, 2021 | Mar. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2018 | Dec. 31, 1988 | Jun. 30, 2024 | Mar. 31, 2024 | Dec. 31, 2023 | Jun. 30, 2022 | |
Accounts Payable, Current | $ 1,314,661 | $ 1,314,661 | $ 1,566,745 | |||||||||||||||||
Regulatory Liability, Noncurrent | 3,488,314 | 3,488,314 | 3,116,926 | |||||||||||||||||
System Energy [Member] | ||||||||||||||||||||
Accounts Payable, Current | 43,623 | 43,623 | 73,580 | |||||||||||||||||
Regulatory Liability, Noncurrent | $ 668,309 | 668,309 | 782,912 | |||||||||||||||||
System Energy [Member] | Unit Power Sales Agreement Complaint [Member] | ||||||||||||||||||||
Regulatory Liability, Noncurrent | 178,000 | |||||||||||||||||||
System Energy [Member] | Entergy Arkansas [Member] | Unit Power Sales Agreement Complaint [Member] | ||||||||||||||||||||
Payments for Legal Settlements | $ 92,000 | |||||||||||||||||||
System Energy [Member] | Grand Gulf [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.65% | |||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 52% | |||||||||||||||||||
System Energy [Member] | Grand Gulf [Member] | Entergy Louisiana [Member] | Subsequent Event [Member] | ||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.65% | |||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 52% | |||||||||||||||||||
Entergy Louisiana [Member] | ||||||||||||||||||||
Accounts Payable, Current | $ 406,932 | 406,932 | 467,414 | |||||||||||||||||
Regulatory Liability, Noncurrent | 1,692,861 | 1,692,861 | 1,407,689 | |||||||||||||||||
Entergy New Orleans [Member] | ||||||||||||||||||||
Accounts Payable, Current | 38,150 | 38,150 | 39,813 | |||||||||||||||||
Regulatory Liability, Noncurrent | 259,613 | 259,613 | 90,434 | |||||||||||||||||
Entergy Arkansas [Member] | ||||||||||||||||||||
Payments for Legal Settlements | $ 135,000 | |||||||||||||||||||
Accounts Payable, Current | 196,722 | 196,722 | 215,502 | |||||||||||||||||
Regulatory Liability, Noncurrent | 803,680 | 803,680 | $ 759,181 | |||||||||||||||||
Return on Equity and Capital Structure Complaints [Member] | System Energy [Member] | ||||||||||||||||||||
Earned return on equity | 10.94% | |||||||||||||||||||
Recommended adjustment to earned return on equity | 9.32% | |||||||||||||||||||
Estimated return on equity complaint refund | 25,300 | 25,300 | ||||||||||||||||||
Return on equity complaint, estimated annual rate reduction | 15,000 | 15,000 | ||||||||||||||||||
Return on Equity and Capital Structure Complaints [Member] | System Energy [Member] | Maximum [Member] | ||||||||||||||||||||
ALJ recommended equity capital structure, percentage | 48.15% | |||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | System Energy [Member] | ||||||||||||||||||||
Disallowance of future sale-leaseback renewal costs recovery | $ 11,500 | |||||||||||||||||||
Calculated refund of sale-leaseback renewal rental costs, including interest | $ 89,800 | |||||||||||||||||||
One-time accumulated deferred income tax credit | $ 25,200 | |||||||||||||||||||
Calculated net refund for excess depreciation expense | 13,700 | |||||||||||||||||||
Payments for Legal Settlements | $ 103,500 | |||||||||||||||||||
Recalculated Payments for Legal Settlements | $ 35,700 | |||||||||||||||||||
Recalculated proceeds from legal settlements | 67,800 | |||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | System Energy [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||
Recalculated proceeds from legal settlements | 27,300 | |||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | System Energy [Member] | Grand Gulf [Member] | ||||||||||||||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 11.50% | |||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy Louisiana [Member] | System Energy [Member] | ||||||||||||||||||||
Payments for Legal Settlements | 18,200 | |||||||||||||||||||
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy New Orleans [Member] | System Energy [Member] | ||||||||||||||||||||
Payments for Legal Settlements | 22,300 | |||||||||||||||||||
Unit Power Sales Agreement Complaint [Member] | System Energy [Member] | ||||||||||||||||||||
Potential settlement refund | $ 18,000 | |||||||||||||||||||
FERC ALJ initial decision recommended refunds | 69,900 | |||||||||||||||||||
Interest component of FERC ALJ initial decision recommended refunds | $ 97,800 | |||||||||||||||||||
FERC ALJ initial decision modification to cash working capital allowance | $ 36,400 | |||||||||||||||||||
System Energy Settlement with the APSC [Member] | System Energy [Member] | ||||||||||||||||||||
Regulatory liabilitity related to settlements and potential future refunds | $ 588,000 | |||||||||||||||||||
System Energy Settlement with the APSC [Member] | System Energy [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.65% | |||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 52% | |||||||||||||||||||
System Energy Settlement with the APSC [Member] | Entergy Arkansas [Member] | ||||||||||||||||||||
Cumulative proceeds from legal settlements | 142,000 | |||||||||||||||||||
Proceeds from Legal Settlements | $ 49,500 | |||||||||||||||||||
System Energy Settlement with the City Council [Member] | System Energy [Member] | ||||||||||||||||||||
Regulatory liabilitity related to settlements and potential future refunds | 588,000 | |||||||||||||||||||
System Energy Settlement with the City Council [Member] | System Energy [Member] | Entergy New Orleans [Member] | Unit Power Sales Agreement Complaint [Member] | ||||||||||||||||||||
Accounts Payable, Current | $ 98,000 | |||||||||||||||||||
System Energy Settlement with the City Council [Member] | Entergy New Orleans [Member] | ||||||||||||||||||||
Cumulative proceeds from legal settlements | $ 116,000 | |||||||||||||||||||
Proceeds from Legal Settlements | $ 18,000 | |||||||||||||||||||
System Energy Settlement with the City Council [Member] | Entergy Arkansas and and Entergy Mississippi | Grand Gulf [Member] | ||||||||||||||||||||
Long-Term Contract for Purchase of Electric Power, Share of Plant Output Being Purchased | 65% | |||||||||||||||||||
System Energy Settlement with the City Council [Member] | Entergy Arkansas and Entergy Mississippi and Entergy New Orleans [Member] | Grand Gulf [Member] | ||||||||||||||||||||
Long-Term Contract for Purchase of Electric Power, Share of Plant Output Being Purchased | 85% | |||||||||||||||||||
System Energy Settlement with the LPSC | System Energy [Member] | ||||||||||||||||||||
Regulatory liabilitity related to settlements and potential future refunds | $ 588,000 | |||||||||||||||||||
System Energy Settlement with the LPSC | System Energy [Member] | Entergy Louisiana [Member] | Unit Power Sales Agreement Complaint [Member] | ||||||||||||||||||||
Accounts Payable, Current | $ 80,000 | $ 80,000 | ||||||||||||||||||
System Energy Settlement with the LPSC | Entergy Louisiana [Member] | Subsequent Event [Member] | ||||||||||||||||||||
Cumulative proceeds from legal settlements | $ 95,000 | |||||||||||||||||||
Proceeds from Legal Settlements | $ 15,000 | |||||||||||||||||||
Pension Costs Amendment Proceeding [Member] | System Energy [Member] | ||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 8,900 |
Equity (Narrative) (Details)
Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | 6 Months Ended | |||||||||||
Jul. 26, 2024 | Jun. 27, 2024 | May 30, 2024 | May 15, 2024 | Mar. 26, 2024 | Mar. 11, 2024 | Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | May 31, 2024 | Apr. 30, 2024 | Dec. 31, 2023 | |
Stock Issued During Period, Shares, Treasury Stock Reissued | 10,757 | ||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 1.13 | $ 1.07 | $ 2.26 | $ 2.14 | |||||||||
Forward Contracts [Member] | |||||||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,094,239 | 156,101 | 1,502,247 | 78,050 | |||||||||
Equity Distribution Program [Member] | |||||||||||||
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $ 2,000,000 | $ 2,000,000 | |||||||||||
Forward Sale Agreement, Aggregate Compensation to Forward Sellers | $ 1,100 | $ 1,300 | $ 1,400 | $ 1,200 | $ 300 | ||||||||
Equity Distribution Sales Agreement, Maximum Aggregate Gross Sales Price | 3,000,000 | $ 3,000,000 | $ 3,000,000 | $ 2,000,000 | |||||||||
Equity Distribution Sales Agreement Increase in Aggregate Gross Sales Price | $ 1,000,000 | ||||||||||||
Common Stock [Member] | Equity Distribution Program [Member] | |||||||||||||
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $ 114,500 | $ 134,400 | $ 142,400 | $ 119,200 | $ 29,300 | ||||||||
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ 106.12 | $ 107.93 | $ 110.32 | $ 101.74 | $ 101.92 | ||||||||
Forward Contract Indexed to Issuer's Equity, Indexed Shares | 1,070,003 | 1,233,235 | 1,278,416 | 1,160,415 | 284,922 | ||||||||
Stock Issued During Period, Shares, New Issues | 0 | 0 | |||||||||||
Entergy Louisiana [Member] | |||||||||||||
Members' Equity Attributable to Noncontrolling Interest | $ 45,533 | $ 45,533 | $ 45,107 | ||||||||||
Subsequent Event [Member] | |||||||||||||
Common Stock, Dividends, Per Share, Declared | $ 1.13 |
Equity (Schedule Of Earnings Pe
Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2024 | Mar. 31, 2024 | Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Weighted Average Number of Shares Outstanding, Basic | 213,617,110 | 211,449,211 | 213,380,414 | 211,400,230 | ||
Earnings Per Share, Basic | $ 0.23 | $ 1.85 | $ 0.58 | $ 3.32 | ||
Weighted Average Number of Shares Outstanding, Diluted | 214,376,721 | 212,201,529 | 214,155,768 | 212,173,254 | ||
Earnings Per Share, Diluted | $ 0.23 | $ 1.84 | $ 0.58 | $ 3.31 | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | $ 51,732 | $ 76,536 | $ 392,014 | $ 312,299 | $ 128,268 | $ 704,312 |
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable | 2,810 | 770 | 4,065 | 2,133 | ||
Net Income (Loss) Available to Common Stockholders, Basic | $ 48,922 | $ 391,244 | $ 124,203 | $ 702,179 | ||
Employee Stock Option | ||||||
Incremental Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangements | 300,000 | 300,000 | 300,000 | 300,000 | ||
Average Dilutive Effect Of Stock Options Per Share | $ 0 | $ 0 | $ 0 | $ 0 | ||
Restricted Stock [Member] | ||||||
Incremental Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangements | 500,000 | 500,000 | 500,000 | 500,000 | ||
Average Dilutive Effect Of Restricted Stock Per Share | $ 0 | $ (0.01) | $ 0 | $ (0.01) | ||
Employee Stock Option | ||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,448,982 | 1,315,567 | 1,471,220 | 1,248,743 | ||
Forward Contracts [Member] | ||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 1,094,239 | 156,101 | 1,502,247 | 78,050 |
Equity (Schedule of Accumulated
Equity (Schedule of Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||||
Jun. 30, 2024 | Mar. 31, 2024 | Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||||||
Accumulated other comprehensive income (loss) | $ 80,361 | $ 80,361 | $ (162,460) | |||||
Other Comprehensive Income (Loss), Net of Tax | 246,489 | $ (3,668) | $ (3,292) | $ 2,027 | 242,821 | $ (1,265) | ||
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | ||||||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||||||
Accumulated other comprehensive income (loss) | 80,361 | (166,128) | (193,019) | (189,727) | 80,361 | (193,019) | (162,460) | $ (191,754) |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 246,489 | (3,292) | 242,821 | (1,265) | ||||
Other Comprehensive Income (Loss), Net of Tax | 246,489 | (3,292) | 242,821 | (1,265) | ||||
Entergy Louisiana [Member] | ||||||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||||||
Accumulated other comprehensive income (loss) | 50,751 | 50,751 | 54,798 | |||||
Other Comprehensive Income (Loss), Net of Tax | (2,023) | (2,024) | (1,773) | (786) | (4,047) | (2,559) | ||
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | ||||||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||||||
Accumulated other comprehensive income (loss) | 50,751 | $ 52,774 | 52,811 | $ 54,584 | 50,751 | 52,811 | $ 54,798 | $ 55,370 |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (2,023) | (1,773) | (4,047) | (2,559) | ||||
Other Comprehensive Income (Loss), Net of Tax | $ (2,023) | $ (1,773) | $ (4,047) | $ (2,559) |
Equity (Schedule of Reclassific
Equity (Schedule of Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2024 | Mar. 31, 2024 | Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Other Nonoperating Income (Expense) | $ (342,549) | $ (48,544) | $ (393,294) | $ (102,997) | ||
Income Tax Expense (Benefit) | (33,634) | (134,796) | (54,627) | (55,821) | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | (246,489) | 3,292 | (242,821) | 1,265 | ||
Consolidated net income | 51,732 | $ 76,536 | 392,014 | $ 312,299 | 128,268 | 704,312 |
Reclassification out of Accumulated Other Comprehensive Income [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (246,489) | 3,292 | (242,821) | 1,265 | ||
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) | 3,473 | 3,398 | 6,946 | 6,795 | ||
Defined Benefit Plan, Amortization of Gain (Loss) | 1,641 | 1,633 | 3,037 | 3,295 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (316,974) | (674) | (316,974) | (8,490) | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax | (311,860) | 4,357 | (306,991) | 1,600 | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax | (65,371) | 1,065 | (64,170) | 335 | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | (246,489) | 3,292 | (242,821) | 1,265 | ||
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (246,489) | 3,292 | (242,821) | 1,265 | ||
Entergy Louisiana [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Other Nonoperating Income (Expense) | (20,646) | (42,583) | (67,821) | (90,668) | ||
Income Tax Expense (Benefit) | (20,750) | (68,561) | (59,674) | 42,268 | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | 2,023 | 1,773 | 4,047 | 2,559 | ||
Consolidated net income | 131,114 | $ 182,723 | 263,260 | $ 244,024 | 313,837 | 507,284 |
Entergy Louisiana [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) | 1,136 | 951 | 2,272 | 1,902 | ||
Defined Benefit Plan, Amortization of Gain (Loss) | 1,632 | 1,564 | 3,266 | 3,129 | ||
Defined Benefit Plan, Accumulated Benefit Obligation, (Increase) Decrease for Settlement and Curtailment | 0 | (89) | 0 | (1,529) | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax | 2,768 | 2,426 | 5,538 | 3,502 | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax | 745 | 653 | 1,491 | 943 | ||
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax | 2,023 | 1,773 | 4,047 | 2,559 | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 2,023 | 1,773 | 4,047 | 2,559 | ||
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | $ 2,023 | $ 1,773 | $ 4,047 | $ 2,559 |
Revolving Credit Facilities, _3
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) | 1 Months Ended | 4 Months Ended | 6 Months Ended | |||||
Dec. 31, 2029 | Jun. 30, 2024 | May 31, 2024 | Apr. 30, 2024 | Mar. 31, 2024 | Oct. 31, 2024 | Jun. 30, 2024 | Dec. 31, 2023 | |
Debt Instrument [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | $ 3,000,000 | $ 3,000,000 | $ 2,000,000 | |||||
Junior subordinated debentures due December 2054 | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 1,200,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.125% | |||||||
Commercial Paper [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt, Weighted Average Interest Rate | 5.67% | 5.67% | ||||||
Commercial Paper program limit | $ 2,000,000,000 | $ 2,000,000,000 | ||||||
Commercial Paper | 932,400,000 | 932,400,000 | ||||||
Entergy Arkansas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | $ 250,000,000 | $ 250,000,000 | ||||||
Entergy Arkansas [Member] | 5.45% Series mortgage bonds due June 2034 | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 400,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.45% | |||||||
Entergy Arkansas [Member] | 5.75% Series mortgage bonds due June 2054 | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 400,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.75% | |||||||
Entergy Arkansas [Member] | 3.70% Series mortgage bonds due June 2024 | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.70% | 3.70% | ||||||
Repayments of Debt | $ 375,000,000 | |||||||
Entergy Louisiana [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | 450,000,000 | $ 450,000,000 | ||||||
Entergy Louisiana [Member] | Mortgage Bonds 5.35% Series due March 2034 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 500,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.35% | |||||||
Entergy Louisiana [Member] | Mortgage Bonds 5.70% Series due March 2054 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 700,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.70% | |||||||
Entergy Louisiana [Member] | Mortgage Bonds 5.40% Series due November 2024 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | |||||||
Repayments of Debt | $ 400,000,000 | |||||||
Entergy Mississippi [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | $ 200,000,000 | $ 200,000,000 | ||||||
Entergy Mississippi [Member] | 5.85% Series mortgage bonds due June 2054 | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 300,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.85% | |||||||
Entergy Mississippi [Member] | 3.75% Series mortgage bonds due July 2024 | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.75% | 3.75% | ||||||
Repayments of Debt | $ 100,000,000 | |||||||
Entergy Texas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | 200,000,000 | $ 200,000,000 | ||||||
System Energy [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | 200,000,000 | 200,000,000 | ||||||
Entergy New Orleans [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Authorized Short Term Borrowings | 150,000,000 | 150,000,000 | ||||||
Notes Payable, Noncurrent | 7,004,000 | $ 7,004,000 | $ 7,004,000 | |||||
Entergy New Orleans [Member] | Total amount of mortgage bonds to be issued under bond purchase agreement [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Face Amount | $ 150,000,000 | |||||||
Entergy New Orleans [Member] | Mortgage Bonds 6.25% Series due June 2029 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 35,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.25% | |||||||
Entergy New Orleans [Member] | Mortgage Bonds 6.41% Series due June 2031 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 65,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.41% | |||||||
Entergy New Orleans [Member] | Mortgage Bonds 6.54% Series due June 2034 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Proceeds from Issuance of Debt | $ 50,000,000 | |||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.54% | |||||||
Entergy New Orleans [Member] | 6.25% Unsecured Term Loan due June 2024 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Repayments of Debt | $ 85,000,000 | |||||||
System Energy VIE [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% | |||||||
Entergy Arkansas VIE [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% | |||||||
Entergy Louisiana Waterford VIE [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% | |||||||
Entergy Louisiana River Bend VIE [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% | |||||||
Maximum [Member] | Entergy Arkansas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Consolidated debt ratio of lessees total capitalization | 70% | |||||||
Maximum [Member] | Entergy Louisiana [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Consolidated debt ratio of lessees total capitalization | 70% | |||||||
Maximum [Member] | Entergy Mississippi [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Maximum [Member] | Entergy Texas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Maximum [Member] | System Energy [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Consolidated debt ratio of lessees total capitalization | 70% | |||||||
Maximum [Member] | Entergy New Orleans [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 | ||||||
Minimum [Member] | Entergy Arkansas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |||||||
Minimum [Member] | Entergy Louisiana [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |||||||
Minimum [Member] | Entergy Mississippi [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |||||||
Minimum [Member] | Entergy Texas [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |||||||
Minimum [Member] | Entergy New Orleans [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |||||||
Subsequent Event [Member] | Junior subordinated debentures due December 2054 | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Basis for Effective Rate | 2.67 | |||||||
Subsequent Event [Member] | Entergy Louisiana [Member] | Mortgage Bonds 0.95% Series due October 2024 [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 0.95% | |||||||
Repayments of Debt | $ 1,000,000,000 | |||||||
Credit Facility of $139 Million [Member] | Entergy Nuclear Vermont Yankee [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Maximum Borrowing Capacity | $ 139,000,000 | $ 139,000,000 | ||||||
Line of Credit Facility, Commitment Fee Percentage | 0.20% | |||||||
Long-Term Line of Credit | $ 139,000,000 | $ 139,000,000 | ||||||
Debt, Weighted Average Interest Rate | 6.95% | 6.95% | ||||||
Credit Facility of $3 Billion | ||||||||
Debt Instrument [Line Items] | ||||||||
Line of Credit Facility, Maximum Borrowing Capacity | $ 3,000,000,000 | $ 3,000,000,000 | ||||||
Letters of Credit Outstanding, Amount | 4,000,000 | $ 4,000,000 | ||||||
Line of Credit Facility, Commitment Fee Percentage | 0.225% | |||||||
Long-Term Line of Credit | 0 | $ 0 | ||||||
Line of Credit Facility, Remaining Borrowing Capacity | 2,996,000,000 | 2,996,000,000 | ||||||
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 20,000,000 | $ 20,000,000 | ||||||
Line of Credit Facility, Interest Rate at Period End | 6.94% | 6.94% | ||||||
Line of Credit Facility, Maximum Amount Outstanding During Period | $ 0 | |||||||
Credit Facility of $3 Billion | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Ratio of Indebtedness to Net Capital | 0.65 | 0.65 |
Revolving Credit Facilities, _4
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Line of Credit Facilities) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2024 | Dec. 31, 2023 | |
Letters of Credit Outstanding, Amount | $ 3 | $ 2 |
Credit Facility of $3 Billion | ||
Line of Credit Facility, Maximum Borrowing Capacity | 3,000 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 4 | |
Line of Credit Facility, Interest Rate at Period End | 6.94% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 20 | |
Line of Credit Facility, Commitment Fee Percentage | 0.225% | |
Line of Credit Facility, Remaining Borrowing Capacity | $ 2,996 | |
Entergy Arkansas [Member] | Credit Facility of $25 Million [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | 25 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 0 | |
Line of Credit Facility, Interest Rate at Period End | 7.29% | |
Entergy Arkansas [Member] | Credit Facility of $300 Million | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 300 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 0 | |
Line of Credit Facility, Interest Rate at Period End | 6.57% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 5 | |
Entergy Louisiana [Member] | Credit Facility of $400 Million | ||
Line of Credit Facility, Maximum Borrowing Capacity | 400 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 0 | |
Line of Credit Facility, Interest Rate at Period End | 6.69% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 15 | |
Entergy Mississippi [Member] | Credit Facility of $300 Million | ||
Line of Credit Facility, Maximum Borrowing Capacity | 300 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 0 | |
Line of Credit Facility, Interest Rate at Period End | 6.57% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 5 | |
Entergy New Orleans [Member] | Credit Facility of $25 Million [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | 25 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 0 | |
Line of Credit Facility, Interest Rate at Period End | 7.07% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 10 | |
Entergy Texas [Member] | Credit Facility of $300 Million | ||
Line of Credit Facility, Maximum Borrowing Capacity | 300 | |
Long-Term Line of Credit | 0 | |
Letters of Credit Outstanding, Amount | $ 1.1 | |
Line of Credit Facility, Interest Rate at Period End | 6.69% | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | $ 30 | |
Maximum [Member] | Entergy Arkansas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Louisiana [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Mississippi [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy New Orleans [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Texas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Minimum [Member] | Entergy Arkansas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |
Minimum [Member] | Entergy Louisiana [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% | |
Minimum [Member] | Entergy Texas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.075% |
Revolving Credit Facilities, _5
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Short-Term Debt) (Details) $ in Millions | Jun. 30, 2024 USD ($) |
Entergy Arkansas [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | $ 250 |
Short term borrowings, outstanding | 0 |
Entergy Arkansas [Member] | Credit Facility of $300 Million | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 5 |
Entergy Louisiana [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | 450 |
Short term borrowings, outstanding | 0 |
Entergy Mississippi [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | 200 |
Short term borrowings, outstanding | 40 |
Entergy Mississippi [Member] | Credit Facility of $300 Million | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 5 |
Entergy New Orleans [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | 150 |
Short term borrowings, outstanding | 0 |
Entergy Texas [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | 200 |
Short term borrowings, outstanding | 0 |
Entergy Texas [Member] | Credit Facility of $300 Million | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit | 30 |
System Energy [Member] | |
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract | |
Authorized Short Term Borrowings | 200 |
Short term borrowings, outstanding | $ 0 |
Revolving Credit Facilities, _6
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of nuclear fuel company VIE credit facilities) (Details) $ in Millions | 6 Months Ended |
Jun. 30, 2024 USD ($) | |
Entergy Arkansas VIE [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% |
Entergy Arkansas VIE [Member] | Credit Facility of $80 Million [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Current Borrowing Capacity | $ 80 |
Line of Credit Facility, Interest Rate During Period | 6.44% |
Long-Term Line of Credit | $ 0 |
System Energy VIE [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% |
System Energy VIE [Member] | Credit Facility of $120 Million [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Current Borrowing Capacity | $ 120 |
Line of Credit Facility, Interest Rate During Period | 6.43% |
Long-Term Line of Credit | $ 104.1 |
Entergy Louisiana River Bend VIE [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% |
Entergy Louisiana River Bend VIE [Member] | Credit Facility of $105 Million [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Current Borrowing Capacity | $ 105 |
Line of Credit Facility, Interest Rate During Period | 6.43% |
Long-Term Line of Credit | $ 27.9 |
Entergy Louisiana Waterford VIE [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage | 0.10% |
Entergy Louisiana Waterford VIE [Member] | Credit Facility of $105 Million [Member] | |
Schedule of nuclear fuel company VIE credit facilities [Abstract] | |
Line of Credit Facility, Current Borrowing Capacity | $ 105 |
Line of Credit Facility, Interest Rate During Period | 6.43% |
Long-Term Line of Credit | $ 26.5 |
Revolving Credit Facilities, _7
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of nuclear fuel company VIE notes payable) (Details) $ in Millions | Jun. 30, 2024 USD ($) |
VIE Notes Payable, 5.54% Series O due May 2029 [Member] | Entergy Arkansas VIE [Member] | |
Notes Payable, Noncurrent [Abstract] | |
Debt Instrument, Interest Rate, Stated Percentage | 5.54% |
Notes Payable, Noncurrent | $ 70 |
VIE Notes Payable, 1.84% Series N due July 2026 [Member] | Entergy Arkansas VIE [Member] | |
Notes Payable, Noncurrent [Abstract] | |
Debt Instrument, Interest Rate, Stated Percentage | 1.84% |
Notes Payable, Noncurrent | $ 90 |
VIE Notes Payable, 2.51% Series V Due June 2027 [Member] | Entergy Louisiana River Bend VIE [Member] | |
Notes Payable, Noncurrent [Abstract] | |
Debt Instrument, Interest Rate, Stated Percentage | 2.51% |
Notes Payable, Noncurrent | $ 70 |
VIE Notes Payable, 5.94% Series J due September 2026 [Member] | Entergy Louisiana Waterford VIE [Member] | |
Notes Payable, Noncurrent [Abstract] | |
Debt Instrument, Interest Rate, Stated Percentage | 5.94% |
Notes Payable, Noncurrent | $ 70 |
VIE Notes Payable, 2.05% Series K due September 2027 [Member] | System Energy VIE [Member] | |
Notes Payable, Noncurrent [Abstract] | |
Debt Instrument, Interest Rate, Stated Percentage | 2.05% |
Notes Payable, Noncurrent | $ 90 |
Revolving Credit Facilities, _8
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Long-Term Debt Instruments) (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Long-Term Debt, Fair Value | $ 24,689,579 | $ 22,489,174 |
Long-Term Debt | 27,818,164 | 25,107,896 |
Entergy Arkansas [Member] | ||
Long-Term Debt, Fair Value | 4,470,941 | 4,166,941 |
Long-Term Debt | 5,094,160 | 4,673,080 |
Entergy Louisiana [Member] | ||
Long-Term Debt, Fair Value | 8,964,781 | 8,414,512 |
Long-Term Debt | 10,188,393 | 9,420,689 |
Entergy Mississippi [Member] | ||
Long-Term Debt, Fair Value | 2,093,565 | 1,969,334 |
Long-Term Debt | 2,426,614 | 2,229,510 |
Entergy New Orleans [Member] | ||
Long-Term Debt, Fair Value | 695,029 | 602,716 |
Long-Term Debt | 736,476 | 677,450 |
Entergy Texas [Member] | ||
Long-Term Debt, Fair Value | 2,823,011 | 2,936,130 |
Long-Term Debt | 3,216,909 | 3,225,092 |
System Energy [Member] | ||
Long-Term Debt, Fair Value | 782,228 | 696,168 |
Long-Term Debt | $ 822,762 | $ 738,459 |
Revolving Credit Facilities, _9
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of uncommitted standby letter of credit facilities) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2024 | Dec. 31, 2023 | |
Letters of Credit Outstanding, Amount | $ 3 | $ 2 |
Credit Facility of $25 Million [Member] | Entergy Arkansas [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | 25 | |
Letters of Credit Outstanding, Amount | 0 | |
Credit Facility of $25 Million [Member] | Entergy New Orleans [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | 25 | |
Letters of Credit Outstanding, Amount | 0 | |
Uncommitted Credit Facility of $25 Million [Member] | Entergy Arkansas [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 25 | |
Line of Credit Facility, Commitment Fee Percentage | 0.78% | |
Letters of Credit Outstanding, Amount | $ 12.4 | |
Uncommitted Credit Facility of $125 Million [Member] | Entergy Louisiana [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 125 | |
Line of Credit Facility, Commitment Fee Percentage | 0.78% | |
Letters of Credit Outstanding, Amount | $ 20.7 | |
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 65 | |
Line of Credit Facility, Commitment Fee Percentage | 0.78% | |
Letters of Credit Outstanding, Amount | $ 41.1 | |
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | MISO [Member] | ||
Letters of Credit Outstanding, Amount | 30.9 | |
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | Non-MISO [Member] | ||
Letters of Credit Outstanding, Amount | 10.2 | |
Uncommitted Credit Facility of $15 Million [Member] | Entergy New Orleans [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 15 | |
Line of Credit Facility, Commitment Fee Percentage | 1.625% | |
Letters of Credit Outstanding, Amount | $ 0.5 | |
Uncommitted Credit Facility of $80 Million [Member] | Entergy Texas [Member] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 80 | |
Line of Credit Facility, Commitment Fee Percentage | 1.25% | |
Letters of Credit Outstanding, Amount | $ 79.7 | |
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 Louisiana [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% | |
Minimum [Member] | Entergy Texas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.075% | |
Maximum [Member] | Entergy Arkansas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Mississippi [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Louisiana [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy New Orleans [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% | |
Maximum [Member] | Entergy Texas [Member] | ||
Line of Credit Facility, Commitment Fee Percentage | 0.375% |
Stock Based Compensation (Narra
Stock Based Compensation (Narrative) (Details) - USD ($) | 1 Months Ended | 6 Months Ended | |
Jan. 25, 2024 | Jan. 31, 2024 | Jun. 30, 2024 | |
Employee Stock Option | 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, Options, Grants in Period, Net of Forfeitures | 352,199 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 18.61 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number | 2,599,829 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Exercise Price | $ 101.84 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value | $ 25,700,000 | ||
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, Options, Grants in Period, Net of Forfeitures | 409,947 | ||
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 99.08 | ||
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, Options, Grants in Period, Net of Forfeitures | 158,176 | ||
Percent of performance measure based on relative total shareholder return | 80% | 80% | |
Percent of performance measure based on environmental achievement measure | 20% | 20% | |
Long Term Performance Unit [Member] | Performance measure based on relative total shareholder return [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 | $ 124.65 | ||
Long Term Performance Unit [Member] | Performance measure based on the environmental achievement measure [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 | $ 99.08 |
Stock-Based Compensation (Sched
Stock-Based Compensation (Schedule of Share-Based Payment Arrangement, Expensed and Capitalized, Amount) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Employee Stock Option | ||||
Share-Based Payment Arrangement, Additional Disclosure [Abstract] | ||||
Share-Based Payment Arrangement, Expense | $ 1.1 | $ 1.1 | $ 2.2 | $ 2.1 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 0.3 | 0.3 | 0.6 | 0.6 |
Share-Based Payment Arrangement, Amount Capitalized | 0.5 | 0.6 | 1 | 1.1 |
Other Equity Awards [Member] | ||||
Share-Based Payment Arrangement, Additional Disclosure [Abstract] | ||||
Share-Based Payment Arrangement, Expense | 9.8 | 10.1 | 19.7 | 17.8 |
Share-Based Payment Arrangement, Expense, Tax Benefit | 2.5 | 2.6 | 5 | 4.6 |
Share-Based Payment Arrangement, Amount Capitalized | $ 4.6 | $ 4.4 | $ 9.1 | $ 7.6 |
Retirement And Other Postreti_3
Retirement And Other Postretirement Benefits (Narrative) (Details) | 1 Months Ended | 3 Months Ended | 6 Months Ended | |||
May 31, 2024 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Mar. 31, 2024 USD ($) | |
Entergy Arkansas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | $ 32,328,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | $ 22,784,000 | |||||
Entergy Louisiana [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 28,539,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 19,862,000 | |||||
Entergy Mississippi [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 7,740,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 7,240,000 | |||||
Entergy New Orleans [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 3,432,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 1,499,000 | |||||
Entergy Texas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 5,235,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 3,037,000 | |||||
System Energy [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | $ 9,984,000 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 6,666,000 | |||||
Pension Plan [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Plan Assets, Contributions by Employer | 111,400,000 | |||||
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year | $ 270,000,000 | 270,000,000 | ||||
Non Qualified Pension Plans [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 2,700,000 | $ 8,800,000 | 5,400,000 | $ 18,000,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 4,600,000 | 0 | 9,300,000 | ||
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 68,000 | 63,000 | 136,000 | 513,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 379,000 | ||
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 51,000 | 25,000 | 102,000 | 52,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 | ||
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 83,000 | 87,000 | 166,000 | 639,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 453,000 | ||
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 31,000 | 33,000 | 61,000 | 66,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 | ||
Non Qualified Pension Plans [Member] | Entergy Texas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 62,000 | 63,000 | 124,000 | 126,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 | ||
Qualified Pension Plans [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 339,932,000 | 32,200,000 | 353,074,000 | 196,221,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (325,253,000) | (7,246,000) | (325,253,000) | (145,674,000) | ||
Qualified Pension Plans [Member] | Group annuity contract purchase | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Settlement | $ 1,157,000,000 | |||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 325,000,000 | |||||
Group annuity contract population | 3,400 | |||||
Qualified Pension Plans [Member] | Corporate and Other [Member] | Group annuity contract purchase | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 317,000,000 | |||||
Qualified Pension Plans [Member] | Utility [Member] | Group annuity contract purchase | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 8,000,000 | |||||
Qualified Pension Plans [Member] | Entergy Arkansas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 4,908,000 | 8,247,000 | 9,815,000 | 38,343,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (1,784,000) | 0 | (23,958,000) | ||
Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 2,667,000 | 9,601,000 | 5,334,000 | 52,989,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (2,232,000) | 0 | (38,230,000) | ||
Qualified Pension Plans [Member] | Entergy Mississippi [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 832,000 | 2,360,000 | 1,664,000 | 16,308,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (88,000) | 0 | (11,743,000) | ||
Qualified Pension Plans [Member] | Entergy New Orleans [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 276,000 | 337,000 | 551,000 | 2,482,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (7,000) | 0 | (1,700,000) | ||
Qualified Pension Plans [Member] | Entergy Texas [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 109,000 | 1,880,000 | 217,000 | 12,745,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (592,000) | 0 | (10,270,000) | ||
Qualified Pension Plans [Member] | System Energy [Member] | ||||||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) | 1,909,000 | 2,143,000 | 3,201,000 | 8,861,000 | ||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | $ (611,000) | $ (490,000) | $ (611,000) | $ (5,290,000) |
Retirement And Other Postreti_4
Retirement And Other Postretirement Benefits (Schedule of Net Benefit Costs) (Details) - USD ($) | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | $ 3,126,000 | $ 3,664,000 | $ 6,252,000 | $ 7,328,000 |
Defined Benefit Plan, Interest Cost | 9,852,000 | 10,568,000 | 19,704,000 | 21,136,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (10,569,000) | (9,183,000) | (21,138,000) | (18,366,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (5,720,000) | (5,640,000) | (11,440,000) | (11,280,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | (2,761,000) | (2,862,000) | (5,522,000) | (5,724,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (6,072,000) | (3,453,000) | (12,144,000) | (6,906,000) |
Other Postretirement Benefits Plan [Member] | Entergy Arkansas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 642,000 | 741,000 | 1,284,000 | 1,482,000 |
Defined Benefit Plan, Interest Cost | 1,833,000 | 2,001,000 | 3,666,000 | 4,002,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (4,384,000) | (3,778,000) | (8,768,000) | (7,556,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 524,000 | 524,000 | 1,048,000 | 1,048,000 |
Defined Benefit Plan, Amortization of Gain (Loss) | 0 | 43,000 | 0 | 86,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (1,385,000) | (469,000) | (2,770,000) | (938,000) |
Other Postretirement Benefits Plan [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 700,000 | 845,000 | 1,400,000 | 1,690,000 |
Defined Benefit Plan, Interest Cost | 1,999,000 | 2,233,000 | 3,998,000 | 4,466,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | 0 | 0 | 0 | 0 |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (1,136,000) | (951,000) | (2,272,000) | (1,902,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | (1,738,000) | (1,764,000) | (3,476,000) | (3,528,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (175,000) | 363,000 | (350,000) | 726,000 |
Other Postretirement Benefits Plan [Member] | Entergy Mississippi [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 184,000 | 220,000 | 368,000 | 440,000 |
Defined Benefit Plan, Interest Cost | 486,000 | 543,000 | 972,000 | 1,086,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (1,372,000) | (1,179,000) | (2,744,000) | (2,358,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (239,000) | (239,000) | (478,000) | (478,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 15,000 | 21,000 | 30,000 | 42,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (926,000) | (634,000) | (1,852,000) | (1,268,000) |
Other Postretirement Benefits Plan [Member] | Entergy New Orleans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 51,000 | 59,000 | 102,000 | 118,000 |
Defined Benefit Plan, Interest Cost | 253,000 | 290,000 | 506,000 | 580,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (1,479,000) | (1,316,000) | (2,958,000) | (2,632,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (229,000) | (229,000) | (458,000) | (458,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 19,000 | 117,000 | 38,000 | 234,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (1,385,000) | (1,079,000) | (2,770,000) | (2,158,000) |
Other Postretirement Benefits Plan [Member] | Entergy Texas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 168,000 | 202,000 | 336,000 | 404,000 |
Defined Benefit Plan, Interest Cost | 603,000 | 649,000 | 1,206,000 | 1,298,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (2,539,000) | (2,194,000) | (5,078,000) | (4,388,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (1,093,000) | (1,093,000) | (2,186,000) | (2,186,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 148,000 | 229,000 | 296,000 | 458,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (2,713,000) | (2,207,000) | (5,426,000) | (4,414,000) |
Other Postretirement Benefits Plan [Member] | System Energy [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 175,000 | 189,000 | 350,000 | 378,000 |
Defined Benefit Plan, Interest Cost | 398,000 | 432,000 | 796,000 | 864,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (728,000) | (634,000) | (1,456,000) | (1,268,000) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (73,000) | (73,000) | (146,000) | (146,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 0 | 0 | 0 | 0 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | (228,000) | (86,000) | (456,000) | (172,000) |
Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 4,600,000 | 0 | 9,300,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 2,700,000 | 8,800,000 | 5,400,000 | 18,000,000 |
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 379,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 68,000 | 63,000 | 136,000 | 513,000 |
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 51,000 | 25,000 | 102,000 | 52,000 |
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 453,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 83,000 | 87,000 | 166,000 | 639,000 |
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 31,000 | 33,000 | 61,000 | 66,000 |
Non Qualified Pension Plans [Member] | Entergy Texas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | 0 | 0 | 0 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 62,000 | 63,000 | 124,000 | 126,000 |
Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 23,370,000 | 25,366,000 | 46,746,000 | 51,044,000 |
Defined Benefit Plan, Interest Cost | 65,961,000 | 74,033,000 | 136,587,000 | 149,734,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (89,506,000) | (95,752,000) | (185,486,000) | (193,885,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 14,854,000 | 21,307,000 | 29,974,000 | 43,654,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (325,253,000) | (7,246,000) | (325,253,000) | (145,674,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 339,932,000 | 32,200,000 | 353,074,000 | 196,221,000 |
Qualified Pension Plans [Member] | Entergy Arkansas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 4,100,000 | 4,661,000 | 8,199,000 | 9,410,000 |
Defined Benefit Plan, Interest Cost | 13,217,000 | 13,917,000 | 26,434,000 | 28,197,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (18,155,000) | (17,878,000) | (36,310,000) | (35,954,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 5,746,000 | 5,763,000 | 11,492,000 | 12,732,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (1,784,000) | 0 | (23,958,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 4,908,000 | 8,247,000 | 9,815,000 | 38,343,000 |
Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 5,551,000 | 6,199,000 | 11,102,000 | 12,479,000 |
Defined Benefit Plan, Interest Cost | 13,961,000 | 14,944,000 | 27,922,000 | 30,323,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (19,447,000) | (18,766,000) | (38,894,000) | (37,999,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 2,602,000 | 4,992,000 | 5,204,000 | 9,956,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (2,232,000) | 0 | (38,230,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 2,667,000 | 9,601,000 | 5,334,000 | 52,989,000 |
Qualified Pension Plans [Member] | Entergy Mississippi [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 1,284,000 | 1,456,000 | 2,568,000 | 2,938,000 |
Defined Benefit Plan, Interest Cost | 3,521,000 | 3,824,000 | 7,042,000 | 7,754,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (5,113,000) | (4,635,000) | (10,226,000) | (9,519,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 1,140,000 | 1,627,000 | 2,280,000 | 3,392,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (88,000) | 0 | (11,743,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 832,000 | 2,360,000 | 1,664,000 | 16,308,000 |
Qualified Pension Plans [Member] | Entergy New Orleans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 440,000 | 487,000 | 880,000 | 978,000 |
Defined Benefit Plan, Interest Cost | 1,569,000 | 1,669,000 | 3,138,000 | 3,384,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (2,203,000) | (2,310,000) | (4,407,000) | (4,577,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 470,000 | 484,000 | 940,000 | 997,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (7,000) | 0 | (1,700,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 276,000 | 337,000 | 551,000 | 2,482,000 |
Qualified Pension Plans [Member] | Entergy Texas [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 962,000 | 1,090,000 | 1,923,000 | 2,197,000 |
Defined Benefit Plan, Interest Cost | 2,831,000 | 3,162,000 | 5,662,000 | 6,404,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (4,077,000) | (4,023,000) | (8,154,000) | (8,175,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 393,000 | 1,059,000 | 786,000 | 2,049,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | 0 | (592,000) | 0 | (10,270,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | 109,000 | 1,880,000 | 217,000 | 12,745,000 |
Qualified Pension Plans [Member] | System Energy [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Defined Benefit Plan, Service Cost | 1,383,000 | 1,445,000 | 2,767,000 | 2,912,000 |
Defined Benefit Plan, Interest Cost | 3,386,000 | 3,435,000 | 6,777,000 | 6,963,000 |
Defined Benefit Plan, Expected Return (Loss) on Plan Assets | (4,633,000) | (4,501,000) | (9,281,000) | (9,039,000) |
Defined Benefit Plan, Amortization of Gain (Loss) | 1,162,000 | 1,274,000 | 2,327,000 | 2,735,000 |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement | (611,000) | (490,000) | (611,000) | (5,290,000) |
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total | $ 1,909,000 | $ 2,143,000 | $ 3,201,000 | $ 8,861,000 |
Retirement And Other Postreti_5
Retirement And Other Postretirement Benefits (Schedule of reclassifications out of accumulated other comprehensive income) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | $ 3,473 | $ 3,398 | $ 6,946 | $ 6,795 |
Amortization of Gains (Losses), Before Tax | 1,641 | 1,633 | 3,037 | 3,295 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (311,860) | 4,357 | (306,991) | 1,600 |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | (316,974) | (674) | (316,974) | (8,490) |
Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 1,136 | 951 | 2,272 | 1,902 |
Amortization of Gains (Losses), Before Tax | 1,632 | 1,564 | 3,266 | 3,129 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 2,768 | 2,426 | 5,538 | 3,502 |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | (89) | (1,529) | ||
Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 3,513 | 3,510 | 7,026 | 7,020 |
Amortization of Gains (Losses), Before Tax | 2,615 | 2,897 | 5,230 | 5,796 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 6,128 | 6,407 | 12,256 | 12,816 |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | 0 | 0 | 0 | 0 |
Other Postretirement Benefits Plan [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 1,136 | 951 | 2,272 | 1,902 |
Amortization of Gains (Losses), Before Tax | 1,738 | 1,764 | 3,476 | 3,528 |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | 2,874 | 2,715 | 5,748 | 5,430 |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | 0 | 0 | ||
Non Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | (40) | (112) | (80) | (225) |
Amortization of Gains (Losses), Before Tax | (80) | (160) | (160) | (357) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (120) | (636) | (240) | (2,115) |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | 0 | (364) | 0 | (1,533) |
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 0 | 0 | 0 | 0 |
Amortization of Gains (Losses), Before Tax | (2) | 0 | (2) | (1) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (2) | 0 | (2) | (1) |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | 0 | 0 | ||
Qualified Pension Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 0 | 0 | 0 | 0 |
Amortization of Gains (Losses), Before Tax | (894) | (1,104) | (2,033) | (2,144) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | (317,868) | (1,414) | (319,007) | (9,101) |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | (316,974) | (310) | (316,974) | (6,957) |
Qualified Pension Plans [Member] | Entergy Louisiana [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Amortization of Prior Service Cost Credit, Before Tax | 0 | 0 | 0 | 0 |
Amortization of Gains (Losses), Before Tax | (104) | (200) | (208) | (398) |
Pension and Other Postretirement Costs, Reclassification Out Of Accumulated Other Comprehensive Income, Before Tax | $ (104) | (289) | $ (208) | (1,927) |
Recognized Net Gain (Loss) Due To Settlements, Before Tax | $ (89) | $ (1,529) |
Retirement And Other Postreti_6
Retirement And Other Postretirement Benefits (Schedule of Expected Benefit Payments) (Details) - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2024 | Mar. 31, 2024 | |
Entergy Louisiana [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | $ 48,401 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 19,862 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | $ 28,539 | |
Entergy Mississippi [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | 14,980 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 7,240 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 7,740 | |
Entergy New Orleans [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | 4,931 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 1,499 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 3,432 | |
Entergy Texas [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | 8,272 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 3,037 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 5,235 | |
System Energy [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | 16,650 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | 6,666 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | 9,984 | |
Entergy Arkansas [Member] | ||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | ||
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year | 55,112 | |
Defined Benefit Plan, Plan Assets, Contributions by Employer | $ 22,784 | |
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year | $ 32,328 |
Business Segment Information (S
Business Segment Information (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2024 | Mar. 31, 2024 | Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Segment Financial Information Abstract | |||||||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 2,953,620 | $ 2,846,026 | $ 5,748,248 | $ 5,827,085 | |||
Income Tax Expense (Benefit) | 33,634 | 134,796 | 54,627 | 55,821 | |||
Consolidated net income | 51,732 | $ 76,536 | 392,014 | $ 312,299 | 128,268 | 704,312 | |
Assets | 62,766,297 | 62,766,297 | $ 59,703,396 | ||||
Utility [Member] | |||||||
Segment Financial Information Abstract | |||||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,941,404 | 2,818,747 | 5,713,577 | 5,766,738 | |||
Income Tax Expense (Benefit) | 113,017 | 144,489 | 147,565 | 78,363 | |||
Consolidated net income | 443,319 | 514,498 | 639,299 | 912,664 | |||
Assets | 66,945,968 | 66,945,968 | 63,887,038 | ||||
Corporate and Other [Member] | |||||||
Segment Financial Information Abstract | |||||||
Revenue from Contract with Customer, Excluding Assessed Tax | 12,227 | 27,287 | 34,703 | 60,358 | |||
Income Tax Expense (Benefit) | (79,383) | (9,693) | (92,938) | (22,542) | |||
Consolidated net income | (312,702) | (40,559) | (352,585) | (70,953) | |||
Assets | 925,848 | 925,848 | 836,598 | ||||
Eliminations [Member] | |||||||
Segment Financial Information Abstract | |||||||
Revenue from Contract with Customer, Excluding Assessed Tax | (11) | (8) | (32) | (11) | |||
Income Tax Expense (Benefit) | 0 | 0 | 0 | 0 | |||
Consolidated net income | (78,885) | $ (81,925) | (158,446) | $ (137,399) | |||
Assets | $ (5,105,519) | $ (5,105,519) | $ (5,020,240) |
Risk Management and Fair Valu_3
Risk Management and Fair Values (Narrative) (Details) $ in Millions | 6 Months Ended | |
Jun. 30, 2024 USD ($) GWh MMBTU | Dec. 31, 2023 USD ($) | |
Letters of Credit Outstanding, Amount | $ | $ 3 | $ 2 |
Gas Hedge Contracts [Member] | ||
Maximum Length of Time Hedged in Cash Flow Hedge | 9 months | |
Volume Of Natural Gas Swaps Outstanding | MMBTU | 10,988,500 | |
Gas Hedge Contracts [Member] | Entergy Louisiana [Member] | ||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 0 | |
Gas Hedge Contracts [Member] | Entergy Mississippi [Member] | ||
Maximum Length of Time Hedged in Cash Flow Hedge | 9 months | |
Volume Of Natural Gas Swaps Outstanding | MMBTU | 10,988,500 | |
Gas Hedge Contracts [Member] | Entergy New Orleans [Member] | ||
Volume Of Natural Gas Swaps Outstanding | MMBTU | 0 | |
Financial Transmission Rights (FTRs) [Member] | ||
Volume of Financial Transmission Rights Outstanding | 133,533 | |
Financial Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member] | ||
Letters of Credit Outstanding, Amount | $ | 1.2 | |
Volume of Financial Transmission Rights Outstanding | 31,900 | |
Financial Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member] | ||
Letters of Credit Outstanding, Amount | $ | 0.5 | |
Volume of Financial Transmission Rights Outstanding | 57,200 | |
Financial Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member] | ||
Letters of Credit Outstanding, Amount | $ | 0.3 | |
Volume of Financial Transmission Rights Outstanding | 19,179 | |
Financial Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member] | ||
Volume of Financial Transmission Rights Outstanding | 5,469 | |
Financial Transmission Rights (FTRs) [Member] | Entergy Texas [Member] | ||
Letters of Credit Outstanding, Amount | $ | $ 0.1 | |
Volume of Financial Transmission Rights Outstanding | 19,448 |
Risk Management and Fair Valu_4
Risk Management and Fair Values (Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 3 | $ 3 | $ 2 | ||
Natural Gas Swaps and Options [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 | Other Liabilities, Current | ||
Financial Transmission Rights (FTRs) [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Issuance of Financial Transmission Rights | $ 53 | $ 42 | $ 53 | $ 42 | |
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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current | ||
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 | $ 49 | $ 49 | $ 21 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 | 0 | ||
Other Current Liabilities [Member] | Natural Gas Swaps and Options [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 | 2 | 2 | 11 | ||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 | $ 0 | ||
Entergy Louisiana [Member] | Uncommitted Credit Facility of $125 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | 20.7 | 20.7 | |||
Entergy Louisiana [Member] | Natural Gas Swaps and Options [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 | ||||
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 | ||||
Issuance of Financial Transmission Rights | 21.6 | 18.1 | 21.6 | 18.1 | |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $125 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 0.7 | $ 0.7 | |||
Entergy Louisiana [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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current | Prepaid Expense and Other Assets, Current | ||
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 | $ 19.9 | $ 19.9 | $ 9.8 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0.1 | 0.1 | 0 | ||
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps and Options [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 | ||||
Entergy Mississippi [Member] | Uncommitted Credit Facility of $65 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 41.1 | $ 41.1 | |||
Entergy Mississippi [Member] | Natural Gas Swaps and Options [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 | 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 | ||||
Issuance of Financial Transmission Rights | $ 3.9 | 1.4 | $ 3.9 | 1.4 | |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $65 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 0.6 | $ 0.6 | |||
Entergy Mississippi [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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | 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 | $ 3.6 | $ 3.6 | $ 1.4 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 | 0 | ||
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps and Options [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 | 1.5 | 1.5 | 10.1 | ||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 | $ 0 | ||
Entergy New Orleans [Member] | Natural Gas Swaps and Options [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 | ||||
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Issuance of Financial Transmission Rights | $ 2.8 | 1.4 | $ 2.8 | 1.4 | |
Entergy New Orleans [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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | 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 | $ 2.6 | $ 2.6 | $ 1.1 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 | 0 | ||
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps and Options [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 | ||||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | ||||
Entergy Arkansas [Member] | Uncommitted Credit Facility of $25 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | 12.4 | 12.4 | |||
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 | ||||
Issuance of Financial Transmission Rights | 17.6 | 20.6 | 17.6 | 20.6 | |
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $25 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 1 | $ 1 | |||
Entergy Arkansas [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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | 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 | $ 16.1 | $ 16.1 | $ 6 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | 0 | 0 | 0 | ||
Entergy Texas [Member] | Uncommitted Credit Facility of $80 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | 79.7 | 79.7 | |||
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 | ||||
Issuance of Financial Transmission Rights | 7.3 | $ 0.2 | 7.3 | $ 0.2 | |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $80 Million [Member] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract] | |||||
Letters of Credit Outstanding, Amount | $ 0.4 | $ 0.4 | |||
Entergy Texas [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, Statement of Financial Position [Extensible Enumeration] | Prepaid Expense and Other Assets, Current | 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 | $ 6.6 | $ 6.6 | $ 2.7 | ||
Derivative Asset, Subject to Master Netting Arrangement, Collateral, Obligation to Return Cash Not Offset | $ 0 | $ 0 | $ 0.3 |
Risk Management and Fair Valu_5
Risk Management and Fair Values (Schedule of Derivatives Not Designated As Hedging Instruments) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 3 | $ 3 | $ 2 | ||
Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power | |
Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current | Other Liabilities, Current | ||
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 | Utilities Operating Expense, Fuel Used | |
Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 2 | $ 2 | $ 11 | ||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | 0 | 0 | ||
Entergy Arkansas [Member] | Uncommitted Credit Facility of $25 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | 12.4 | 12.4 | |||
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | 1.2 | ||||
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $25 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 1 | $ 1 | |||
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power | |
Entergy Louisiana [Member] | Uncommitted Credit Facility of $125 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 20.7 | $ 20.7 | |||
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.5 | ||||
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $125 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.7 | $ 0.7 | |||
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power | |
Entergy Louisiana [Member] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | ||||
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] | Utilities Operating Expense, Fuel Used | Utilities Operating Expense, Fuel Used | |||
Entergy Louisiana [Member] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
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 | ||||
Entergy Mississippi [Member] | Uncommitted Credit Facility of $65 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 41.1 | $ 41.1 | |||
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.3 | ||||
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $65 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.6 | $ 0.6 | |||
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power | |
Entergy Mississippi [Member] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | Other Liabilities, Current | Other Liabilities, Current | ||
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 | Utilities Operating Expense, Fuel Used | |
Entergy Mississippi [Member] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 1.5 | $ 1.5 | $ 10.1 | ||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | $ 0 | $ 0 | $ 0 | ||
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power | |
Entergy New Orleans [Member] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Statement of Financial Position [Extensible Enumeration] | Other Liabilities, Current | ||||
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] | Natural Gas Swaps and Options [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Derivative Liability, Subject to Master Netting Arrangement, before Offset | $ 0.6 | ||||
Derivative Liability, Subject to Master Netting Arrangement, Collateral, Right to Reclaim Cash Not Offset | 0 | ||||
Entergy Texas [Member] | Uncommitted Credit Facility of $80 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 79.7 | $ 79.7 | |||
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.1 | ||||
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $80 Million [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items] | |||||
Letters of Credit Outstanding, Amount | $ 0.4 | $ 0.4 | |||
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated as Hedging Instrument [Member] | |||||
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [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 | Utilities Operating Expense, Purchased Power |
Risk Management and Fair Valu_6
Risk Management and Fair Values (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis) (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | $ 1,272,314 | $ 60,939 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 4,000 | |
Replacement Reserve Escrow | 333,000 | 323,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 6,923,000 | 5,277,000 |
Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 2,000 | 11,000 |
Debt Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 1,922,000 | 1,770,000 |
Common trust funds valued using Net Asset Value [Domain] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 3,289,000 | 3,070,000 |
Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 49,000 | 21,000 |
Equity Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 54,000 | 24,000 |
Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 1,272,000 | 61,000 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 4,000 | 8,000 |
Replacement Reserve Escrow | 333,000 | 323,000 |
Equity Securities, FV-NI, Current | 54,000 | 24,000 |
Debt Securities | 721,000 | 611,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,384,000 | 1,027,000 |
Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 2,000 | 11,000 |
Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
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 |
Replacement Reserve Escrow | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 1,201,000 | 1,159,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,201,000 | 1,159,000 |
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
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 |
Replacement Reserve Escrow | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 49,000 | 21,000 |
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 49,000 | 21,000 |
Entergy New Orleans [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 6,532 | 0 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 1,306 | 2,426 |
Replacement Reserve Escrow | 81,700 | 78,700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 92,100 | 82,200 |
Entergy New Orleans [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 600 | |
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 2,600 | 1,100 |
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 | 6,500 | |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 1,300 | 2,400 |
Replacement Reserve Escrow | 81,700 | 78,700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 89,500 | 81,100 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 600 | |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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] | ||
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Replacement Reserve Escrow | 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] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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] | ||
Restricted Cash and Cash Equivalents, Current | 0 | 0 |
Replacement Reserve Escrow | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,600 | 1,100 |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | |
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 2,600 | 1,100 |
Entergy Mississippi [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 3,083 | 6,600 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 800 | 700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 7,500 | 8,700 |
Entergy Mississippi [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 1,500 | 10,100 |
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 3,600 | 1,400 |
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 | 3,100 | 6,600 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 800 | 700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 3,900 | 7,300 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 1,500 | 10,100 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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 | 3,600 | 1,400 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | 0 |
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 3,600 | 1,400 |
Entergy Louisiana [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 185,307 | 517 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 250,400 | 243,800 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,747,700 | 2,361,500 |
Entergy Louisiana [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 400 | |
Entergy Louisiana [Member] | Debt Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 812,600 | 788,100 |
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 1,461,000 | 1,304,700 |
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 19,800 | 9,800 |
Entergy Louisiana [Member] | Equity Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 18,600 | 14,600 |
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 | 185,300 | 500 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 250,400 | 243,800 |
Equity Securities, FV-NI, Current | 18,600 | 14,600 |
Debt Securities | 293,700 | 271,700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 748,000 | 530,600 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 400 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
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 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 518,900 | 516,400 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 518,900 | 516,400 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 0 | 0 |
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 |
Assets, Fair Value Disclosure [Abstract] | ||
Replacement Reserve Escrow | 0 | 0 |
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 19,800 | 9,800 |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member] | ||
Liabilities, Fair Value Disclosure [Abstract] | ||
Liabilities, Fair Value Disclosure on Recurring Basis | 0 | |
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 19,800 | 9,800 |
Entergy Arkansas [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 772,164 | 3,112 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 2,310,800 | 1,423,100 |
Entergy Arkansas [Member] | Debt Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 554,400 | 496,900 |
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 935,000 | 910,700 |
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 16,100 | 6,000 |
Entergy Arkansas [Member] | Equity Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 33,100 | 6,400 |
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 | 772,200 | 3,100 |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 33,100 | 6,400 |
Debt Securities | 165,100 | 129,900 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 970,400 | 139,400 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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 |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 389,300 | 367,000 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 389,300 | 367,000 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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 |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 16,100 | 6,000 |
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 16,100 | 6,000 |
Entergy Texas [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 124,880 | 20,489 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 2,340 | 5,195 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 133,800 | 28,100 |
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 6,600 | 2,400 |
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 | 124,900 | 20,500 |
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | 2,300 | 5,200 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 127,200 | 25,700 |
Entergy Texas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, 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] | ||
Assets, 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 | 6,600 | 2,400 |
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial Transmission Rights (FTRs) [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Derivative Asset | 6,600 | 2,400 |
System Energy [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Cash Equivalents, at Carrying Value | 30,838 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 1,481,100 | 1,342,300 |
System Energy [Member] | Debt Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 554,600 | 485,200 |
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 893,700 | 854,400 |
System Energy [Member] | Equity Securities [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Decommissioning Fund Investments, Fair Value | 2,000 | 2,700 |
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 | 30,800 | |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 2,000 | 2,700 |
Debt Securities | 262,300 | 209,500 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 295,100 | 212,200 |
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 | |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 292,300 | 275,700 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | 292,300 | 275,700 |
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 | |
Assets, Fair Value Disclosure [Abstract] | ||
Equity Securities, FV-NI, Current | 0 | 0 |
Debt Securities | 0 | 0 |
Liabilities, Fair Value Disclosure [Abstract] | ||
Assets, Fair Value Disclosure | $ 0 | 0 |
Entergy Corporation [Member] | ||
Assets, Fair Value Disclosure [Abstract] | ||
Restricted Cash and Cash Equivalents, Current | $ 8,000 |
Risk Management and Fair Valu_7
Risk Management and Fair Values (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation) (Details) - Financial Transmission Rights (FTRs) [Member] - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||||||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Mar. 31, 2024 | Dec. 31, 2023 | Mar. 31, 2023 | Dec. 31, 2022 | |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | $ 49 | $ 40 | $ 49 | $ 40 | $ 9 | $ 21 | $ 7 | $ 19 |
Issuance of Financial Transmission Rights | 53 | 42 | 53 | 42 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 34 | 23 | 75 | 27 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (47) | (32) | (100) | (48) | ||||
Entergy Arkansas [Member] | ||||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 16.1 | 19.6 | 16.1 | 19.6 | 2.8 | 6 | 4 | 10.3 |
Issuance of Financial Transmission Rights | 17.6 | 20.6 | 17.6 | 20.6 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (3.3) | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 7.7 | (0.9) | 31.4 | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (12) | (4.1) | (38.9) | (8) | ||||
Entergy Louisiana [Member] | ||||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 19.8 | 16.7 | 19.8 | 16.7 | 4.1 | 9.8 | 2.5 | 7.3 |
Issuance of Financial Transmission Rights | 21.6 | 18.1 | 21.6 | 18.1 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 19.6 | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 19.1 | 15.6 | 29.6 | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (25) | (19.5) | (41.2) | (28.3) | ||||
Entergy Mississippi [Member] | ||||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 3.6 | 1.2 | 3.6 | 1.2 | 0.6 | 1.4 | 0.2 | 0.6 |
Issuance of Financial Transmission Rights | 3.9 | 1.4 | 3.9 | 1.4 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 3.7 | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 1.2 | 2.6 | 1.4 | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (2.1) | (3) | (3.1) | (4.5) | ||||
Entergy New Orleans [Member] | ||||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 2.6 | 1.5 | 2.6 | 1.5 | 0.5 | 1.1 | 0.3 | 0.8 |
Issuance of Financial Transmission Rights | 2.8 | 1.4 | 2.8 | 1.4 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 1.7 | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 2.6 | 1.3 | 3.1 | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (3.3) | (1.5) | (4.4) | (2.4) | ||||
Entergy Texas [Member] | ||||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 6.6 | 1.2 | 6.6 | 1.2 | $ 1.2 | $ 2.4 | $ 0.1 | |
Issuance of Financial Transmission Rights | 7.3 | 0.2 | 7.3 | 0.2 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 5.1 | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset | 2.7 | 4.6 | 9 | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value | $ (0.1) | |||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | $ (4.6) | $ (3.5) | $ (12.1) | $ (4.2) |
Decommissioning Trust Funds (Na
Decommissioning Trust Funds (Narrative) (Details) - USD ($) | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Decommissioning Trust Funds (Textual) [Abstract] | |||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 2,051,000,000 | $ 2,051,000,000 | $ 1,885,000,000 | ||
Average Coupon Rate of Debt Securities Percentage | 3.63% | 3.63% | |||
Average Duration of Debt Securities in Years | 6 years 1 month 20 days | ||||
Average Maturity of Debt Securities, Years | 10 years 5 months 8 days | ||||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 161,000,000 | $ 136,000,000 | $ 330,000,000 | $ 260,000,000 | |
Debt Securities, Available-for-Sale, Realized Gain | 0 | 0 | 1,000,000 | 1,000,000 | |
Debt Securities, Available-for-Sale, Realized Loss | 14,000,000 | 8,000,000 | 20,000,000 | 17,000,000 | |
Equity Securities, FV-NI, Unrealized Gain (Loss) | 78,000,000 | 366,000,000 | |||
Debt Securities [Member] | |||||
Decommissioning Trust Funds (Textual) [Abstract] | |||||
Deferred Tax Asset, Debt Securities, Available-for-Sale, Unrealized Loss | 0 | 0 | 0 | ||
Entergy Arkansas [Member] | |||||
Decommissioning Trust Funds (Textual) [Abstract] | |||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 611,500,000 | $ 611,500,000 | 548,100,000 | ||
Average Coupon Rate of Debt Securities Percentage | 2.92% | 2.92% | |||
Average Duration of Debt Securities in Years | 5 years 9 months 18 days | ||||
Average Maturity of Debt Securities, Years | 7 years 6 months 3 days | ||||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 5,500,000 | 900,000 | $ 17,900,000 | 16,600,000 | |
Debt Securities, Available-for-Sale, Realized Gain | 100,000 | 0 | 100,000 | 0 | |
Debt Securities, Available-for-Sale, Realized Loss | 400,000 | 100,000 | 900,000 | 1,700,000 | |
Equity Securities, FV-NI, Unrealized Gain (Loss) | 21,700,000 | 105,700,000 | |||
Entergy Louisiana [Member] | |||||
Decommissioning Trust Funds (Textual) [Abstract] | |||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 847,800,000 | $ 847,800,000 | 813,900,000 | ||
Average Coupon Rate of Debt Securities Percentage | 4.03% | 4.03% | |||
Average Duration of Debt Securities in Years | 6 years 4 months 9 days | ||||
Average Maturity of Debt Securities, Years | 12 years 9 months 14 days | ||||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 62,500,000 | 65,200,000 | $ 110,900,000 | 132,600,000 | |
Percentage Interest in River Bend | 30% | ||||
Debt Securities, Available-for-Sale, Realized Gain | 100,000 | 100,000 | $ 200,000 | 500,000 | |
Debt Securities, Available-for-Sale, Realized Loss | 4,800,000 | 4,000,000 | 7,700,000 | 9,000,000 | |
Equity Securities, FV-NI, Unrealized Gain (Loss) | 42,300,000 | 166,600,000 | |||
System Energy [Member] | |||||
Decommissioning Trust Funds (Textual) [Abstract] | |||||
Debt Securities, Available-for-Sale, Amortized Cost | $ 591,600,000 | $ 591,600,000 | $ 523,200,000 | ||
Average Coupon Rate of Debt Securities Percentage | 3.78% | 3.78% | |||
Average Duration of Debt Securities in Years | 6 years 2 months 4 days | ||||
Average Maturity of Debt Securities, Years | 10 years 10 days | ||||
Proceeds from Sale of Debt Securities, Available-for-Sale | $ 93,500,000 | 69,900,000 | $ 201,500,000 | 111,200,000 | |
Debt Securities, Available-for-Sale, Realized Gain | 0 | 0 | 200,000 | 0 | |
Debt Securities, Available-for-Sale, Realized Loss | 8,400,000 | $ 4,100,000 | 11,900,000 | $ 6,300,000 | |
Equity Securities, FV-NI, Unrealized Gain (Loss) | $ 14,300,000 | $ 93,300,000 |
Decommissioning Trust Funds (Sc
Decommissioning Trust Funds (Schedule of Available-for-Sale Securities Reconciliation) (Details) - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale | $ 1,922 | $ 1,770 |
Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 139 | 134 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 10 | 19 |
Debt Securities, Available-for-Sale | 1,922 | 1,770 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale | 554.4 | 496.9 |
Entergy Arkansas [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 59 | 53.6 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 1.9 | 2.4 |
Debt Securities, Available-for-Sale | 554.4 | 496.9 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale | 812.6 | 788.1 |
Entergy Louisiana [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 39.8 | 37.4 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 4.6 | 11.7 |
Debt Securities, Available-for-Sale | 812.6 | 788.1 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale | 554.6 | 485.2 |
System Energy [Member] | Debt Securities [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Available-for-Sale, Unrealized Loss Position | 40.2 | 42.5 |
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax | 3.2 | 4.5 |
Debt Securities, Available-for-Sale | $ 554.6 | $ 485.2 |
Decommissioning Trust Funds (_2
Decommissioning Trust Funds (Schedule of Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions | Jun. 30, 2024 | Dec. 31, 2023 |
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | $ 453 | $ 134 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 949 | 999 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 1,402 | 1,133 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 5 | 6 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 134 | 128 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 139 | 134 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 70.8 | 22.5 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 388.7 | 403.4 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 459.5 | 425.9 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 1.1 | 0.4 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 57.9 | 53.2 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 59 | 53.6 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 275.6 | 69.8 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 340.4 | 356.1 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 616 | 425.9 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 2.7 | 0.9 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 37.1 | 36.5 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | 39.8 | 37.4 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale [Line Items] | ||
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value | 106.8 | 42.1 |
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value | 219.8 | 239.1 |
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value | 326.6 | 281.2 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months | 1.6 | 4.5 |
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer | 38.6 | 38 |
Debt Securities, Available-for-Sale, Unrealized Loss Position | $ 40.2 | $ 42.5 |
Decommissioning Trust Funds (_3
Decommissioning Trust Funds (Schedule of Investments Classified by Contractual Maturity Date) (Details) - USD ($) $ in Thousands | Jun. 30, 2024 | Dec. 31, 2023 |
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five | $ 568,000 | $ 517,000 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 | 575,000 | 504,000 |
Available for Sale Securities Debt Maturities After Ten to Fifteen Years Fair Value | 120,000 | 121,000 |
Available for Sale Securities, Debt Maturities After Fifteen to Twenty Years, Fair Value | 186,000 | 179,000 |
Available for Sale Securities Debt Maturities After Twenty Years Fair Value | 397,000 | 367,000 |
Debt Securities, Available-for-Sale | 1,922,000 | 1,770,000 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One | 76,000 | 82,000 |
Decommissioning Fund Investments | 5,265,003 | 4,863,710 |
Entergy Arkansas [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five | 156,300 | 132,200 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 | 234,800 | 205,700 |
Available for Sale Securities Debt Maturities After Ten to Fifteen Years Fair Value | 31,700 | 39,900 |
Available for Sale Securities, Debt Maturities After Fifteen to Twenty Years, Fair Value | 59,800 | 49,600 |
Available for Sale Securities Debt Maturities After Twenty Years Fair Value | 28,300 | 24,200 |
Debt Securities, Available-for-Sale | 554,400 | 496,900 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One | 43,500 | 45,300 |
Decommissioning Fund Investments | 1,522,508 | 1,414,009 |
Entergy Louisiana [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five | 189,200 | 181,600 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 | 186,900 | 170,000 |
Available for Sale Securities Debt Maturities After Ten to Fifteen Years Fair Value | 79,800 | 70,200 |
Available for Sale Securities, Debt Maturities After Fifteen to Twenty Years, Fair Value | 84,700 | 90,200 |
Available for Sale Securities Debt Maturities After Twenty Years Fair Value | 244,700 | 244,700 |
Debt Securities, Available-for-Sale | 812,600 | 788,100 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One | 27,300 | 31,400 |
Decommissioning Fund Investments | 2,292,174 | 2,107,384 |
System Energy [Member] | ||
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract] | ||
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five | 222,100 | 203,400 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 | 153,500 | 128,600 |
Available for Sale Securities Debt Maturities After Ten to Fifteen Years Fair Value | 8,100 | 10,700 |
Available for Sale Securities, Debt Maturities After Fifteen to Twenty Years, Fair Value | 41,000 | 38,800 |
Available for Sale Securities Debt Maturities After Twenty Years Fair Value | 124,500 | 98,400 |
Debt Securities, Available-for-Sale | 554,600 | 485,200 |
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One | 5,400 | 5,300 |
Decommissioning Fund Investments | $ 1,450,321 | $ 1,342,317 |
Income Taxes (Narrative) (Detai
Income Taxes (Narrative) (Details) - USD ($) $ in Thousands | 3 Months Ended | 5 Months Ended | 6 Months Ended | 12 Months Ended | |||
Mar. 31, 2024 | Dec. 31, 2023 | May 31, 2024 | Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2024 | Apr. 30, 2024 | |
Regulatory Liability, Noncurrent | $ 3,116,926 | $ 3,488,314 | |||||
Increase (Decrease) in Regulatory Liabilities | 380,394 | $ 308,058 | |||||
Entergy New Orleans [Member] | |||||||
Regulatory Liability, Noncurrent | 90,434 | 259,613 | |||||
Increase (Decrease) in Regulatory Liabilities | 167,529 | 30,722 | |||||
Entergy Arkansas [Member] | |||||||
Regulatory Liability, Noncurrent | 759,181 | 803,680 | |||||
Increase (Decrease) in Regulatory Liabilities | 71,529 | $ 97,349 | |||||
State Effective Income Tax Rate, Percent | 4.80% | ||||||
Regulatory Liability For Income Taxes - Current and Non Current | $ 31,000 | ||||||
Entergy Arkansas [Member] | Subsequent Event [Member] | |||||||
State Effective Income Tax Rate, Percent | 4.30% | ||||||
Credits expected to be shared with customers from resolution of the 2016-2018 IRS audit [Member] | Entergy New Orleans [Member] | |||||||
Regulatory Liability, Noncurrent | $ 138,000 | 60,000 | $ 138,000 | ||||
Regulatory charge, net of tax | 57,000 | $ 44,000 | |||||
Increase (Decrease) in Regulatory Liabilities | $ 78,000 |
Variable Interest Entities (Nar
Variable Interest Entities (Narrative) (Details) - USD ($) $ in Thousands | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | |
Variable Interest Entity [Line Items] | |||
Assets | $ 62,766,297 | $ 59,703,396 | |
Entergy New Orleans [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 2,269,084 | 2,097,975 | |
Entergy Louisiana [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 29,970,921 | 29,109,470 | |
Members' Equity Attributable to Noncontrolling Interest | $ 45,533 | 45,107 | |
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | |||
Variable Interest Entity [Line Items] | |||
LURC's beneficial interest in the storm trust, percentage | 1% | ||
Members' Equity Attributable to Noncontrolling Interest | $ 30,600 | 30,500 | |
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | Entergy Finance Company [Member] | |||
Variable Interest Entity [Line Items] | |||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | $ 2,900,000 | 3,000,000 | |
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | |||
Variable Interest Entity [Line Items] | |||
LURC's beneficial interest in the storm trust, percentage | 1% | ||
Members' Equity Attributable to Noncontrolling Interest | $ 14,900 | 14,600 | |
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | Entergy Finance Company [Member] | |||
Variable Interest Entity [Line Items] | |||
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value | 1,500,000 | 1,500,000 | |
System Energy [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 4,559,811 | 4,312,363 | |
System Energy [Member] | Grand Gulf [Member] | |||
Variable Interest Entity [Line Items] | |||
Payments on lease including interest | 8,600 | $ 8,600 | |
Entergy Arkansas [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 14,976,041 | 13,672,858 | |
Members' Equity Attributable to Noncontrolling Interest | 18,675 | 21,599 | |
Entergy Arkansas [Member] | AR Searcy Partnership, LLC [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 132,500 | 134,000 | |
Ownership Interest in Partnership, Carrying Value | 112,900 | 111,200 | |
Entergy Mississippi [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 6,506,100 | 6,228,006 | |
Members' Equity Attributable to Noncontrolling Interest | 14,718 | 18,753 | |
Entergy Mississippi [Member] | MS Sunflower Partnership, LLC [Member] | |||
Variable Interest Entity [Line Items] | |||
Assets | 167,700 | 163,200 | |
Ownership Interest in Partnership, Carrying Value | $ 131,100 | $ 128,400 |
Revenue Recognition (Schedule o
Revenue Recognition (Schedule of Disaggregation of Revenue) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2024 | Jun. 30, 2023 | Jun. 30, 2024 | Jun. 30, 2023 | |
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 2,953,620 | $ 2,846,026 | $ 5,748,248 | $ 5,827,085 |
Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 608,798 | 616,347 | 1,230,843 | 1,199,096 |
Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,276,124 | 1,205,612 | 2,478,564 | 2,550,820 |
Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 442,894 | 445,130 | 857,750 | 857,558 |
Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 199,341 | 188,016 | 392,302 | 396,836 |
Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 519,077 | 464,430 | 963,568 | 971,936 |
Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,906,047 | 2,785,244 | 5,612,553 | 5,668,654 |
Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 608,798 | 616,347 | 1,230,843 | 1,199,096 |
Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,261,444 | 1,191,909 | 2,434,237 | 2,511,661 |
Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 442,894 | 445,130 | 857,750 | 857,558 |
Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 178,664 | 168,216 | 335,605 | 337,911 |
Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 519,077 | 464,430 | 963,568 | 971,936 |
Natural Gas, US Regulated [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 35,357 | 33,503 | 101,024 | 98,084 |
Natural Gas, US Regulated [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 14,680 | 13,703 | 44,327 | 39,159 |
Natural Gas, US Regulated [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 20,677 | 19,800 | 56,697 | 58,925 |
Natural Gas, US Regulated [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 0 | 0 | 0 | 0 |
Other [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 12,216 | 27,279 | 34,671 | 60,347 |
Residential [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,009,836 | 951,424 | 2,080,177 | 1,992,883 |
Residential [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 204,822 | 204,808 | 480,574 | 444,307 |
Residential [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 353,975 | 334,246 | 699,003 | 694,892 |
Residential [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 163,049 | 163,001 | 341,666 | 332,390 |
Residential [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 71,842 | 68,535 | 139,520 | 132,101 |
Residential [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 216,148 | 180,834 | 419,414 | 389,193 |
Commercial [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 713,282 | 692,788 | 1,405,133 | 1,407,089 |
Commercial [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 132,950 | 136,591 | 274,258 | 261,927 |
Commercial [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 265,869 | 253,365 | 522,565 | 531,543 |
Commercial [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 142,173 | 142,997 | 274,491 | 276,673 |
Commercial [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 57,360 | 56,095 | 110,585 | 110,164 |
Commercial [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 114,930 | 103,740 | 223,234 | 226,782 |
Industrial [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 792,721 | 750,177 | 1,541,679 | 1,613,899 |
Industrial [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 138,786 | 153,817 | 288,193 | 285,053 |
Industrial [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 458,420 | 407,045 | 880,017 | 916,949 |
Industrial [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 49,180 | 54,738 | 95,607 | 106,153 |
Industrial [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 7,602 | 7,562 | 14,580 | 14,975 |
Industrial [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 138,733 | 127,015 | 263,282 | 290,769 |
Governmental [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 65,861 | 63,816 | 131,172 | 131,153 |
Governmental [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 4,433 | 4,945 | 9,133 | 9,605 |
Governmental [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 21,223 | 19,407 | 43,044 | 42,481 |
Governmental [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 14,061 | 14,971 | 27,390 | 28,854 |
Governmental [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 19,167 | 17,896 | 37,521 | 35,694 |
Governmental [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 6,977 | 6,597 | 14,084 | 14,519 |
Billed Retail [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,581,700 | 2,458,205 | 5,158,161 | 5,145,024 |
Billed Retail [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 480,991 | 500,161 | 1,052,158 | 1,000,892 |
Billed Retail [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,099,487 | 1,014,063 | 2,144,629 | 2,185,865 |
Billed Retail [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 368,463 | 375,707 | 739,154 | 744,070 |
Billed Retail [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 155,971 | 150,088 | 302,206 | 292,934 |
Billed Retail [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 476,788 | 418,186 | 920,014 | 921,263 |
Sales for Resale [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 54,579 | 68,262 | 133,583 | 176,209 |
Sales for Resale [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 43,842 | 48,266 | 82,807 | 114,283 |
Sales for Resale [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 80,823 | 80,248 | 163,551 | 163,484 |
Sales for Resale [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 21,260 | 26,073 | 69,193 | 64,816 |
Sales for Resale [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 8,575 | 11,075 | 21,075 | 35,985 |
Sales for Resale [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 3,015 | 1,986 | 4,922 | 4,431 |
Non-Customer [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 11,955 | 11,446 | 26,962 | 55,633 |
Non-Customer [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,232 | 2,113 | 4,804 | 4,397 |
Non-Customer [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 6,464 | 6,226 | 13,442 | 44,373 |
Non-Customer [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,453 | 2,384 | 4,887 | 4,832 |
Non-Customer [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,307 | 1,386 | 2,732 | 2,908 |
Non-Customer [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 50 | (603) | (104) | (843) |
Non-Customer [Member] | Other [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 12,216 | 27,279 | 34,671 | 60,347 |
Other Electric [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 257,813 | 247,331 | 293,847 | 291,788 |
Other Electric [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 81,733 | 65,807 | 91,074 | 79,524 |
Other Electric [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 74,670 | 91,372 | 112,615 | 117,939 |
Other Electric [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 50,718 | 40,966 | 44,516 | 43,840 |
Other Electric [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 12,811 | 5,667 | 9,592 | 6,084 |
Other Electric [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 39,224 | 44,861 | 38,736 | 47,085 |
Customer [Member] | Electricity [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 2,894,092 | 2,773,798 | 5,585,591 | 5,613,021 |
Customer [Member] | Electricity [Member] | Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 606,566 | 614,234 | 1,226,039 | 1,194,699 |
Customer [Member] | Electricity [Member] | Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 1,254,980 | 1,185,683 | 2,420,795 | 2,467,288 |
Customer [Member] | Electricity [Member] | Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 440,441 | 442,746 | 852,863 | 852,726 |
Customer [Member] | Electricity [Member] | Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | 177,357 | 166,830 | 332,873 | 335,003 |
Customer [Member] | Electricity [Member] | Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from Contract with Customer, Excluding Assessed Tax | $ 519,027 | $ 465,033 | $ 963,672 | $ 972,779 |
Revenue Recognition (Schedule_2
Revenue Recognition (Schedule of Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions | 6 Months Ended | |||
Jun. 30, 2024 | Jun. 30, 2023 | Dec. 31, 2023 | Dec. 31, 2022 | |
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | $ 16.6 | $ 21.8 | $ 25.9 | $ 30.9 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 15.3 | 15.5 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (46) | (51.5) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | 21.4 | 26.9 | ||
Entergy Arkansas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | 4.3 | 5.2 | 7.2 | 6.5 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 2.6 | 3.2 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (10.7) | (13.2) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | 5.2 | 8.7 | ||
Entergy Louisiana [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | 3.4 | 4.9 | 6.1 | 7.6 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 6.2 | 7 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (15.6) | (21.4) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | 6.7 | 11.7 | ||
Entergy Mississippi [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | 2.2 | 2.4 | 3.3 | 2.5 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 2.2 | 2.1 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (7.4) | (3.7) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | 4.1 | 1.5 | ||
Entergy New Orleans [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | 5.8 | 7.6 | 7.8 | 11.9 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 1.4 | 0.7 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (7.1) | (6.5) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | 3.7 | 1.5 | ||
Entergy Texas [Member] | ||||
Disaggregation of Revenue [Line Items] | ||||
Allowance for Credit Loss, Receivable, Other, Current | 0.9 | 1.7 | $ 1.5 | $ 2.4 |
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease) | 2.9 | 2.5 | ||
Accounts Receivable, Allowance for Credit Loss, Writeoff | (5.2) | (6.7) | ||
Accounts Receivable, Allowance for Credit Loss, Recovery | $ 1.7 | $ 3.5 |
Asset Retirement Obligations (N
Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions | 3 Months Ended | |
Jun. 30, 2024 | Mar. 31, 2024 | |
Entergy Arkansas [Member] | ANO [Member] | ||
Asset Retirement Obligation, Revision of Estimate | $ 14.4 | |
Entergy Arkansas [Member] | Independence and White Bluff | ||
Asset Retirement Obligation, Revision of Estimate | $ 31 | |
Entergy Mississippi [Member] | Independence | ||
Asset Retirement Obligation, Revision of Estimate | $ 9 |
Business Combinations and Ass_2
Business Combinations and Asset Acquisitions (Narrative) (Details) $ in Thousands | 1 Months Ended | 6 Months Ended | |||
Feb. 29, 2024 USD ($) | Dec. 31, 2024 USD ($) | Jun. 30, 2024 USD ($) | Jun. 30, 2023 USD ($) | Jun. 30, 2020 MW | |
Asset Acquisition [Line Items] | |||||
Payments to Acquire Productive Assets | $ 172,614 | $ 30,433 | |||
Entergy Arkansas [Member] | |||||
Asset Acquisition [Line Items] | |||||
Payments to Acquire Productive Assets | $ 169,694 | $ 0 | |||
Walnut Bend Solar facility [Member] | Entergy Arkansas [Member] | |||||
Asset Acquisition [Line Items] | |||||
Generation Capacity | MW | 100 | ||||
Payments to Acquire Productive Assets | $ 170,000 | ||||
Walnut Bend Solar facility [Member] | Entergy Arkansas [Member] | Subsequent Event [Member] | |||||
Asset Acquisition [Line Items] | |||||
Payments to Acquire Productive Assets | $ 20,000 |
Uncategorized Items - etr-20240
Label | Element | Value |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | $ 132,548,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 224,164,000 |
Entergy Texas [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 3,497,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 21,986,000 |
Entergy Arkansas [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 5,278,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 3,632,000 |
Entergy New Orleans [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 26,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 4,464,000 |
Entergy Mississippi [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 16,979,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 6,630,000 |
System Energy [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 2,940,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 60,000 |
Entergy Louisiana [Member] | ||
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | 56,613,000 |
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents | us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalents | $ 2,772,000 |