Entergy Utility Group, Inc. 1ST MTG BD 66 (ENO) 10-K 25 Feb 22 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2021	Jan. 31, 2022	Jun. 30, 2021
Document Transition Report	false
Entity File Number	1-11299
Document Quarterly Report	true
Entity Registrant Name	ENTERGY CORPORATION
Entity Central Index Key	0000065984
Document Type	10-K
Document Period End Date	Dec. 31, 2021
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	639 Loyola Avenue
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70113
City Area Code	504
Local Phone Number	576-4000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Public Float			$ 20
Entity Common Stock, Shares Outstanding		203,027,662
Entity Tax Identification Number	72-1229752
ICFR Auditor Attestation Flag	true
Auditor Name	Deloitte & Touche LLP
Auditor Location	New Orleans, Louisiana
Auditor Firm ID	34
Entergy Arkansas [Member]
Entity File Number	1-10764
Entity Registrant Name	ENTERGY ARKANSAS, LLC
Entity Central Index Key	0000007323
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	425 West Capitol Avenue
Entity Address, City or Town	Little Rock
Entity Address, State or Province	AR
Entity Address, Postal Zip Code	72201
City Area Code	501
Local Phone Number	377-4000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	83-1918668
ICFR Auditor Attestation Flag
Entergy Louisiana [Member]
Entity File Number	1-32718
Entity Registrant Name	ENTERGY LOUISIANA, LLC
Entity Central Index Key	0001348952
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	4809 Jefferson Highway
Entity Address, City or Town	Jefferson
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70121
City Area Code	504
Local Phone Number	576-4000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	47-4469646
ICFR Auditor Attestation Flag
Entergy Mississippi [Member]
Entity File Number	1-31508
Entity Registrant Name	ENTERGY MISSISSIPPI, LLC
Entity Central Index Key	0000066901
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	308 East Pearl Street
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39201
City Area Code	601
Local Phone Number	368-5000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	83-1950019
ICFR Auditor Attestation Flag
Entergy New Orleans [Member]
Entity File Number	1-35747
Entity Registrant Name	ENTERGY NEW ORLEANS, LLC
Entity Central Index Key	0000071508
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	1600 Perdido Street
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70112
City Area Code	504
Local Phone Number	670-3700
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	82-2212934
ICFR Auditor Attestation Flag
Entergy Texas [Member]
Title of 12(g) Security	Common Stock, no par value
Entity File Number	1-34360
Entity Registrant Name	ENTERGY TEXAS, INC.
Entity Central Index Key	0001427437
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line One	2107 Research Forest Drive
Entity Address, City or Town	The Woodlands
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77380
City Area Code	409
Local Phone Number	981-2000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	61-1435798
ICFR Auditor Attestation Flag
System Energy [Member]
Entity File Number	1-09067
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
Entity Central Index Key	0000202584
Entity Incorporation, State or Country Code	AR
Entity Address, Address Line One	1340 Echelon Parkway
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39213
City Area Code	601
Local Phone Number	368-5000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	72-0752777
ICFR Auditor Attestation Flag
NEW YORK STOCK EXCHANGE, INC. [Member]
Title of 12(b) Security	Common Stock, $0.01 Par Value
Trading Symbol	ETR
Security Exchange Name	NYSE
CHICAGO STOCK EXCHANGE, INC [Member]
Title of 12(b) Security	Common Stock, $0.01 Par Value
Trading Symbol	ETR
Security Exchange Name	CHX
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Arkansas [Member]
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Trading Symbol	EAI
Security Exchange Name	NYSE
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Louisiana [Member]
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Trading Symbol	ELC
Security Exchange Name	NYSE
Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Mississippi [Member]
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due October 2066
Trading Symbol	EMP
Security Exchange Name	NYSE
Mortgage Bonds, 5.0% Series, Due December 2052 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy New Orleans [Member]
Title of 12(b) Security	Mortgage Bonds, 5.0% Series due December 2052
Trading Symbol	ENJ
Security Exchange Name	NYSE
Mortgage Bonds, 5.5% Series, Due April 2066 [Member] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy New Orleans [Member]
Title of 12(b) Security	Mortgage Bonds, 5.50% Series due April 2066
Trading Symbol	ENO
Security Exchange Name	NYSE
5.375% Series A Preferred Stock, Cumulative, No Par Value [Domain] | NEW YORK STOCK EXCHANGE, INC. [Member] | Entergy Texas [Member]
Title of 12(b) Security	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)
Trading Symbol	ETI/PR
Security Exchange Name	NYSE

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 11,742,896	$ 10,113,636	$ 10,878,673
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	2,458,096	1,564,371	2,029,638
Nuclear refueling outage expenses	172,636	184,157	204,927
Operation and maintenance expense	2,968,621	3,002,626	3,272,381
Asset Impairment Charges	263,625	26,623	290,027
Decommissioning	306,411	381,861	400,802
Taxes, Other	660,290	652,840	643,745
Other Depreciation and Amortization	1,684,286	1,613,086	1,480,016
Other regulatory charges (credits) - net	111,628	14,609	(26,220)
Costs and Expenses	9,897,270	8,344,441	9,488,176
Operating income (loss)	1,845,626	1,769,195	1,390,497
OTHER INCOME
Allowance for equity funds used during construction	70,473	119,430	144,974
Investment Income, Net	430,466	392,818	547,912
Miscellaneous - net	(201,778)	(210,633)	(252,539)
TOTAL	299,161	301,615	440,347
INTEREST EXPENSE
Interest expense	863,712	837,981	807,382
Allowance for borrowed funds used during construction	(29,018)	(52,318)	(64,957)
TOTAL	834,694	785,663	742,425
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	1,310,093	1,285,147	1,088,419
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	1,118,719	1,406,653	1,258,244
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	227	18,319	17,018
Net Income (Loss) Available to Common Stockholders, Basic	$ 1,118,492	$ 1,388,334	$ 1,241,226
Earnings per average common share:
Basic (in usd per share)	$ 5.57	$ 6.94	$ 6.36
Diluted (in usd per share)	$ 5.54	$ 6.90	$ 6.30
Basic average number of common shares outstanding	200,941,511	200,106,945	195,195,858
Diluted average number of common shares outstanding	201,873,024	201,102,220	196,999,284
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 10,873,995	$ 9,046,643	$ 9,429,978
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	170,610	124,008	153,954
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	698,291	942,985	1,294,741
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	1,271,677	904,268	1,192,860
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,338,590	2,084,494	2,259,594
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	347,166	271,896	458,907
Nuclear refueling outage expenses	51,141	55,737	68,769
Operation and maintenance expense	687,418	669,518	720,217
Decommissioning	77,696	73,319	68,030
Taxes, Other	127,249	121,057	115,869
Other Depreciation and Amortization	361,479	338,029	307,351
Other regulatory charges (credits) - net	(31,501)	(35,310)	(11,186)
Costs and Expenses	1,901,152	1,681,936	1,932,597
Operating income (loss)	437,438	402,558	326,997
OTHER INCOME
Allowance for equity funds used during construction	15,273	15,019	15,499
Investment Income, Net	76,953	35,579	26,020
Miscellaneous - net	(22,278)	(21,908)	(18,566)
TOTAL	69,948	28,690	22,953
INTEREST EXPENSE
Interest expense	140,348	144,834	140,087
Allowance for borrowed funds used during construction	(6,641)	(6,595)	(6,332)
TOTAL	133,707	138,239	133,755
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	373,679	293,009	216,195
Income Tax Expense (Benefit)	75,195	47,777	(46,769)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	298,484	245,232	262,964
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	(18,092)	0	0
Net Income (Loss) Available to Common Stockholders, Basic	316,576	245,232	262,964
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,338,590	2,084,494	2,259,594
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Arkansas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	280,504	187,690	204,640
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	5,068,448	4,069,862	4,285,175
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	1,302,291	700,152	845,108
Nuclear refueling outage expenses	49,373	55,305	54,170
Operation and maintenance expense	1,034,427	969,630	994,637
Decommissioning	68,575	65,225	59,346
Taxes, Other	224,079	208,902	194,222
Other Depreciation and Amortization	656,132	609,931	535,791
Other regulatory charges (credits) - net	38,245	(584)	(105,203)
Costs and Expenses	4,141,668	3,205,041	3,388,533
Operating income (loss)	926,780	864,821	896,642
OTHER INCOME
Allowance for equity funds used during construction	28,648	38,151	74,023
Investment Income, Net	282,200	225,627	231,985
Miscellaneous - net	(125,886)	(116,366)	(115,427)
TOTAL	184,962	147,412	190,581
INTEREST EXPENSE
Interest expense	350,227	331,352	309,493
Allowance for borrowed funds used during construction	(12,878)	(19,147)	(35,430)
TOTAL	337,349	312,205	274,063
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	774,393	700,028	813,160
Income Tax Expense (Benefit)	120,409	(382,324)	121,623
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	653,984	1,082,352	691,537
Net Income (Loss) Available to Common Stockholders, Basic	653,984	1,082,352	691,537
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	4,994,459	4,019,063	4,223,027
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	73,989	50,799	62,148
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	768,546	596,480	810,462
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,406,346	1,247,854	1,323,043
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	181,511	187,087	277,425
Operation and maintenance expense	298,129	288,543	266,175
Taxes, Other	111,712	101,525	105,318
Other Depreciation and Amortization	226,545	209,252	170,886
Other regulatory charges (credits) - net	5,913	(15,219)	14,993
Costs and Expenses	1,121,844	1,011,659	1,119,289
Operating income (loss)	284,502	236,195	203,754
OTHER INCOME
Allowance for equity funds used during construction	8,101	6,726	8,356
Investment Income, Net	53	272	1,412
Miscellaneous - net	(8,791)	(9,253)	(4,478)
TOTAL	(637)	(2,255)	5,290
INTEREST EXPENSE
Interest expense	75,124	68,945	61,785
Allowance for borrowed funds used during construction	(3,416)	(2,778)	(3,532)
TOTAL	71,708	66,167	58,253
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	212,157	167,773	150,791
Income Tax Expense (Benefit)	45,323	27,190	30,866
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	166,834	140,583	119,925
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,406,346	1,247,854	1,323,043
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Mississippi [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	298,034	240,471	284,492
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	768,852	633,841	686,223
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	150,018	76,781	105,217
Operation and maintenance expense	145,377	125,756	121,057
Taxes, Other	53,569	57,454	55,270
Other Depreciation and Amortization	73,480	64,012	56,072
Other regulatory charges (credits) - net	13,177	1,854	21,616
Costs and Expenses	704,189	569,429	617,538
Operating income (loss)	64,663	64,412	68,685
OTHER INCOME
Allowance for equity funds used during construction	2,371	6,339	9,941
Investment Income, Net	48	120	428
Miscellaneous - net	(1,240)	316	(6,038)
TOTAL	1,179	6,775	4,331
INTEREST EXPENSE
Interest expense	29,164	29,105	24,463
Allowance for borrowed funds used during construction	(1,056)	(3,049)	(4,262)
TOTAL	28,108	26,056	20,201
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	37,734	45,131	52,815
Income Tax Expense (Benefit)	5,936	(4,207)	186
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	31,798	49,338	52,629
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	672,231	560,632	594,417
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	96,621	73,209	91,806
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	268,568	243,572	258,306
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,902,511	1,587,125	1,488,955
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	335,742	238,428	162,544
Operation and maintenance expense	281,713	250,170	258,924
Taxes, Other	94,989	72,909	76,366
Other Depreciation and Amortization	214,838	177,738	153,286
Other regulatory charges (credits) - net	59,581	90,398	88,770
Costs and Expenses	1,575,804	1,340,276	1,342,453
Operating income (loss)	326,707	246,849	146,502
OTHER INCOME
Allowance for equity funds used during construction	9,892	44,073	28,445
Investment Income, Net	837	1,201	3,072
Miscellaneous - net	721	(28)	546
TOTAL	11,450	45,246	32,063
INTEREST EXPENSE
Interest expense	87,787	92,920	86,333
Allowance for borrowed funds used during construction	(3,980)	(18,940)	(13,269)
TOTAL	83,807	73,980	73,064
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	254,350	218,115	105,501
Income Tax Expense (Benefit)	25,526	3,042	(53,896)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	228,824	215,073	159,397
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	1,909	1,882	580
Net Income (Loss) Available to Common Stockholders, Basic	226,915	213,191	158,817
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,902,511	1,587,125	1,488,955
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Texas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	588,941	510,633	602,563
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	58,313	23,026	82,438
Nuclear refueling outage expenses	27,244	27,737	33,376
Operation and maintenance expense	214,322	178,249	206,444
Decommissioning	38,693	37,181	35,729
Taxes, Other	27,842	28,657	29,018
Other Depreciation and Amortization	105,978	110,395	106,630
Other regulatory charges (credits) - net	26,214	(26,531)	(35,210)
Costs and Expenses	498,606	378,714	458,425
Operating income (loss)	72,242	116,744	114,985
OTHER INCOME
Allowance for equity funds used during construction	6,188	9,122	8,709
Investment Income, Net	82,744	36,478	29,488
Miscellaneous - net	(18,991)	(10,012)	(5,516)
TOTAL	69,941	35,588	32,681
INTEREST EXPENSE
Interest expense	38,393	34,467	35,328
Allowance for borrowed funds used during construction	(1,047)	(1,809)	(2,131)
TOTAL	37,346	32,658	33,197
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	104,837	119,674	114,469
Income Tax Expense (Benefit)	(1,977)	20,543	15,349
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	106,814	99,131	99,120
Net Income (Loss) Available to Common Stockholders, Basic	106,814	99,131	99,120
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 570,848	$ 495,458	$ 573,410

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 1,118,719	$ 1,406,653	$ 1,258,244
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(29,754)	(55,487)	115,026
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	195,929	22,496	(25,150)
Net unrealized investment gains	(49,496)	30,704	27,183
Net other comprehensive income (loss) for the period	116,679	(2,287)	117,059
Total comprehensive income	1,235,398	1,404,366	1,375,303
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	227	18,319	17,018
Comprehensive Income Attributable to Entergy Corporation	1,235,171	1,386,047	1,358,285
Entergy Louisiana [Member]
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	653,984	1,082,352	691,537
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	3,951	(235)	10,715
Net other comprehensive income (loss) for the period	3,951	(235)	10,715
Total comprehensive income	$ 657,935	$ 1,082,117	$ 702,252

Consolidated Statements Of Co_2

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension and other postretirement liabilities, tax expense	$ 55,161	$ 5,600	$ (6,539)
Net unrealized investment gains, tax expense	(28,435)	17,586	14,023
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	(7,935)	(14,776)	28,516
Entergy Louisiana [Member]
Pension and other postretirement liabilities, tax expense	$ 1,523	$ (83)	$ 3,781

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
OPERATING ACTIVITIES
Consolidated net income	$ 1,118,719	$ 1,406,653	$ 1,258,244
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	2,242,944	2,257,750	2,182,313
Deferred income taxes, investment tax credits, and non-current taxes accrued	248,719	(131,114)	193,950
Asset Write-Offs, Impairments, And Related Charges	263,599	26,379	226,678
Changes in working capital:
Receivables	(84,629)	(139,296)	(101,227)
Fuel inventory	18,359	(27,458)	(28,173)
Accounts payable	269,797	137,457	(71,898)
Taxes accrued	(21,183)	207,556	(20,784)
Interest accrued	(10,640)	7,662	937
Deferred fuel costs	(466,050)	(49,484)	172,146
Other working capital accounts	(53,883)	(143,451)	(3,108)
Changes in provisions for estimated losses	(85,713)	(291,193)	19,914
Increase (Decrease) in Other Regulatory Assets	536,707	784,494	545,559
Increase (Decrease) in Regulatory Liabilities	43,631	238,669	(14,781)
Changes in pension and other postretirement liabilities	(897,167)	50,379	187,124
Other	(250,917)	76,149	639,149
Net cash flow provided by operating activities	2,300,713	2,689,866	2,816,627
INVESTING ACTIVITIES
Construction/capital expenditures	(6,087,296)	(4,694,076)	(4,197,667)
Allowance for equity funds used during construction	70,473	119,430	144,862
Nuclear fuel purchases	(166,512)	(215,664)	(128,366)
Payment for purchase of plant or assets	(168,304)	(247,121)	(305,472)
Net proceeds from sale of assets	17,421	0	28,932
Proceeds from insurance	0	0	7,040
Changes in securitization account	13,669	5,099	3,298
Payments To Storm Reserve Escrow Account	(25)	(2,273)	(8,038)
Receipts from storm reserve escrow account	83,105	297,588	0
Decrease (increase) in other investments	2,343	(12,755)	30,319
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	49,236	72,711	2,369
Proceeds from nuclear decommissioning trust fund sales	5,553,629	3,107,812	4,121,351
Investment in nuclear decommissioning trust funds	(5,547,015)	(3,203,057)	(4,208,870)
Net cash flow used in investing activities	(6,179,276)	(4,772,306)	(4,510,242)
Proceeds from the issuance of:
Long-term debt	8,308,427	12,619,201	9,304,396
Preferred stock of subsidiary	0	0	33,188
Common stock and treasury stock	5,977	42,600	93,862
Proceeds from Issuance of Common Stock	200,776	0	607,650
Retirement of long-term debt	(4,827,827)	(8,152,378)	(7,619,380)
Payments for Repurchase of Preferred Stock and Preference Stock	0	0	50,000
Changes in credit borrowings and commercial paper - net	426,312	319,238	(4,389)
Other	43,221	(7,524)	(7,732)
Dividends paid:
Common stock	(775,122)	(748,342)	(711,573)
Preferred stock	(18,319)	(18,502)	(16,438)
Net cash flow provided by financing activities	2,562,023	3,415,817	1,638,362
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(1,316,540)	1,333,377	(55,253)
Cash and cash equivalents at beginning of period	1,759,099	425,722	480,975
Cash and cash equivalents at end of period	442,559	1,759,099	425,722
Cash paid (received) during the period for:
Interest - net of amount capitalized	843,228	803,923	778,209
Income taxes	98,377	(31,228)	(40,435)
Proceeds from Noncontrolling Interests	51,202	0	0
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	298,484	245,232	262,964
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	503,539	490,457	465,299
Deferred income taxes, investment tax credits, and non-current taxes accrued	100,459	87,019	94,368
Changes in working capital:
Receivables	17,682	(24,507)	(58,077)
Fuel inventory	(7,081)	(10,066)	(10,597)
Accounts payable	27,967	(22,773)	3,059
Taxes accrued	7,753	6	24,942
Interest accrued	(5,637)	(43)	3,895
Deferred fuel costs	(162,458)	(1,186)	72,560
Other working capital accounts	(53,343)	(11,061)	18,783
Changes in provisions for estimated losses	6,915	6,289	14,901
Increase (Decrease) in Other Regulatory Assets	(142,706)	165,534	131,873
Increase (Decrease) in Regulatory Liabilities	21,066	106,878	39,293
Changes in pension and other postretirement liabilities	(175,863)	42,576	5,831
Other	172,973	83,469	127,582
Net cash flow provided by operating activities	549,216	659,818	677,766
INVESTING ACTIVITIES
Construction/capital expenditures	(722,628)	(775,595)	(641,525)
Allowance for equity funds used during construction	15,273	15,019	15,306
Nuclear fuel purchases	(84,302)	(100,678)	(54,344)
Payment for purchase of plant or assets	(131,770)	(5,988)	0
Decrease (increase) in other investments	0	4,036	630
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	0	55,001	0
Proceeds from nuclear decommissioning trust fund sales	530,628	321,360	317,377
Investment in nuclear decommissioning trust funds	(524,783)	(336,392)	(336,519)
Net cash flow used in investing activities	(898,193)	(795,709)	(676,293)
Proceeds from the issuance of:
Long-term debt	719,284	1,071,121	834,038
Retirement of long-term debt	(728,917)	(632,175)	(548,952)
Other	38,291	2,188	(7,055)
Dividends paid:
Common stock	(50,000)	(95,000)	(115,000)
Net cash flow provided by financing activities	169,764	324,500	1,927
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(179,213)	188,609	3,400
Cash and cash equivalents at beginning of period	192,128	3,519	119
Cash and cash equivalents at end of period	12,915	192,128	3,519
Cash paid (received) during the period for:
Interest - net of amount capitalized	143,561	140,735	131,134
Income taxes	(18,933)	(21,971)	(33,989)
Proceeds from sale of nuclear fuel	16,279	30,638	22,782
Change in money pool receivable - net	3,110	(3,110)	0
Proceeds from Noncontrolling Interests	51,202	0	0
Change in money pool payable - net	139,904	(21,634)	(161,104)
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	653,984	1,082,352	691,537
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	818,389	783,616	685,062
Deferred income taxes, investment tax credits, and non-current taxes accrued	175,700	(356,256)	196,533
Changes in working capital:
Receivables	(58,466)	(79,451)	13,942
Fuel inventory	7,722	(9,067)	(7,195)
Accounts payable	358,536	160,659	(33,375)
Taxes accrued	21,631	50,576	(38,827)
Interest accrued	803	4,505	4,294
Deferred fuel costs	(43,124)	(57,895)	24,234
Other working capital accounts	(45,517)	(76,284)	(62,536)
Changes in provisions for estimated losses	(449)	(295,480)	9,664
Increase (Decrease) in Other Regulatory Assets	1,050,600	410,855	210,134
Increase (Decrease) in Regulatory Liabilities	(16,478)	71,698	(35,881)
Changes in pension and other postretirement liabilities	(164,263)	12,199	35,162
Other	(394,658)	(192,669)	36,478
Net cash flow provided by operating activities	1,052,526	1,072,986	1,236,002
INVESTING ACTIVITIES
Construction/capital expenditures	(3,621,775)	(1,960,787)	(1,673,194)
Allowance for equity funds used during construction	28,648	38,151	74,023
Nuclear fuel purchases	(85,419)	(92,831)	(85,984)
Net proceeds from sale of assets	15,000	0	0
Payments for (Proceeds from) Productive Assets	0	(236,999)	0
Proceeds from insurance	0	0	7,040
Payment For Proceed From Other Investing Activities	8,691	5,090	2,369
Changes in securitization account	2,700	951	(32)
Payments To Storm Reserve Escrow Account	0	(1,488)	(6,353)
Receipts from storm reserve escrow account	0	297,363	0
Proceeds from nuclear decommissioning trust fund sales	944,703	347,021	412,559
Investment in nuclear decommissioning trust funds	(1,004,888)	(372,227)	(442,501)
Net cash flow used in investing activities	(3,700,199)	(1,944,671)	(1,653,634)
Proceeds from the issuance of:
Long-term debt	3,769,166	3,675,083	2,691,133
Retirement of long-term debt	(1,895,091)	(1,962,635)	(2,199,053)
Other	(849)	(10,423)	9,368
Dividends paid:
Common stock	(60,000)	(21,500)	(208,000)
Net cash flow provided by financing activities	1,938,226	1,597,699	376,274
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(709,447)	726,014	(41,358)
Cash and cash equivalents at beginning of period	728,020	2,006	43,364
Cash and cash equivalents at end of period	18,573	728,020	2,006
Cash paid (received) during the period for:
Interest - net of amount capitalized	337,926	318,352	296,842
Income taxes	(18,453)	(14,714)	15,272
Proceeds from sale of nuclear fuel	13,254	44,511	11,596
Change in money pool receivable - net	(1,113)	(13,426)	46,843
Proceeds from Contributions from Parent	125,000	0	0
Change in money pool payable - net	0	(82,826)	82,826
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	166,834	140,583	119,925
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	226,545	209,252	170,886
Deferred income taxes, investment tax credits, and non-current taxes accrued	64,868	36,827	32,547
Changes in working capital:
Receivables	10,260	(1,889)	(17,245)
Fuel inventory	6,806	(1,978)	(3,208)
Accounts payable	27,068	22,794	(226)
Taxes accrued	(1,811)	17,423	13,109
Interest accrued	(3,606)	1,989	(1,331)
Deferred fuel costs	(136,569)	(55,711)	78,418
Other working capital accounts	(9,522)	630	(5,557)
Changes in provisions for estimated losses	(8,476)	(3,517)	(1,121)
Increase (Decrease) in Other Regulatory Assets	(4,909)	89,369	34,923
Increase (Decrease) in Regulatory Liabilities	21,930	(18,672)	(21,524)
Changes in pension and other postretirement liabilities	(51,828)	11,319	6,534
Other	(33,552)	(30,633)	(3,668)
Net cash flow provided by operating activities	350,960	300,314	339,952
INVESTING ACTIVITIES
Construction/capital expenditures	(654,352)	(555,287)	(432,600)
Allowance for equity funds used during construction	8,101	6,726	8,356
Payments for (Proceeds from) Productive Assets	0	(28,612)	(305,472)
Decrease (increase) in other investments	53	1,719	(655)
Net cash flow used in investing activities	(686,654)	(530,762)	(733,684)
Proceeds from the issuance of:
Long-term debt	398,284	165,385	437,153
Retirement of long-term debt	0	0	(150,000)
Other	1,535	6,964	(8,774)
Dividends paid:
Common stock	0	(10,000)	0
Net cash flow provided by financing activities	383,303	178,865	408,379
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	47,609	(51,583)	14,647
Cash and cash equivalents at beginning of period	18	51,601	36,954
Cash and cash equivalents at end of period	47,627	18	51,601
Cash paid (received) during the period for:
Interest - net of amount capitalized	76,245	64,536	60,533
Income taxes	(19,672)	(8,084)	(12,204)
Change in money pool receivable - net	(40,456)	44,692	(3,313)
Proceeds from Contributions from Parent	0	0	130,000
Change in money pool payable - net	(16,516)	16,516	0
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	31,798	49,338	52,629
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	73,480	64,012	56,072
Deferred income taxes, investment tax credits, and non-current taxes accrued	12,573	3,938	21,350
Changes in working capital:
Receivables	(42,612)	(12,003)	(9,372)
Fuel inventory	(967)	(58)	(387)
Accounts payable	22,457	5,582	(5,571)
Taxes accrued	(315)	398	234
Interest accrued	(104)	1,179	550
Deferred fuel costs	9,737	(7,048)	3,630
Other working capital accounts	(3,233)	(13,156)	5,021
Changes in provisions for estimated losses	(83,569)	1,356	1,948
Increase (Decrease) in Other Regulatory Assets	(18,173)	7,427	29,567
Increase (Decrease) in Regulatory Liabilities	4,985	(4,728)	(22,105)
Changes in pension and other postretirement liabilities	(32,144)	(14,063)	(14,624)
Other	(68,549)	3,296	(55,796)
Net cash flow provided by operating activities	78,808	64,024	115,604
INVESTING ACTIVITIES
Construction/capital expenditures	(220,284)	(228,983)	(229,560)
Allowance for equity funds used during construction	2,371	6,339	9,941
Payments to Acquire Buildings	0	(1,584)	0
Changes in securitization account	1,365	(1,375)	236
Payments To Storm Reserve Escrow Account	(7)	(433)	(1,752)
Receipts from storm reserve escrow account	83,045	0	0
Net cash flow used in investing activities	(169,920)	(220,845)	(204,310)
Proceeds from the issuance of:
Long-term debt	183,403	138,925	113,876
Retirement of long-term debt	(36,873)	(56,593)	(35,376)
Other	(774)	146	(1,475)
Dividends paid:
Net cash flow provided by financing activities	133,948	150,830	75,046
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	42,836	(5,991)	(13,660)
Repayment of long-term payable due to Entergy Louisiana	(1,618)	(1,838)	(1,979)
Cash and cash equivalents at beginning of period	26	6,017	19,677
Cash and cash equivalents at end of period	42,862	26	6,017
Cash paid (received) during the period for:
Interest - net of amount capitalized	28,009	26,673	22,873
Income taxes	(3,839)	3,392	(5,310)
Change in money pool receivable - net	(36,410)	5,191	16,825
Proceeds from Contributions from Parent	0	60,000	0
Change in money pool payable - net	(10,190)	10,190	0
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	228,824	215,073	159,397
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	214,838	177,738	153,286
Deferred income taxes, investment tax credits, and non-current taxes accrued	48,813	36,033	20,143
Changes in working capital:
Receivables	(16,455)	(30,082)	58,445
Fuel inventory	10,819	(5,938)	(4,926)
Accounts payable	(5,718)	(23,692)	(33,646)
Taxes accrued	(3,420)	2,730	(3,805)
Interest accrued	(1,854)	1,864	(5,363)
Deferred fuel costs	(133,636)	72,355	(6,696)
Other working capital accounts	(12,105)	(11,837)	(13,822)
Changes in provisions for estimated losses	(140)	274	(5,748)
Increase (Decrease) in Other Regulatory Assets	(103,380)	12,065	(85,400)
Increase (Decrease) in Regulatory Liabilities	(28,747)	(57,477)	(105,517)
Changes in pension and other postretirement liabilities	(42,502)	(28,825)	(7,152)
Other	5,164	(39,174)	3,257
Net cash flow provided by operating activities	356,933	375,325	286,739
INVESTING ACTIVITIES
Construction/capital expenditures	(702,754)	(895,857)	(898,090)
Allowance for equity funds used during construction	9,892	44,073	28,526
Payments to Acquire Buildings	(36,534)	(4,931)	0
Net proceeds from sale of assets	67,920	0	0
Changes in securitization account	9,604	1,487	2,465
Net cash flow used in investing activities	(647,271)	(848,648)	(878,280)
Proceeds from the issuance of:
Long-term debt	127,931	937,725	986,019
Retirement of long-term debt	(269,435)	(367,565)	(578,593)
Other	6,848	(4,106)	1,189
Dividends paid:
Common stock	0	(30,000)	0
Preferred stock	(1,881)	(2,064)	0
Net cash flow provided by financing activities	41,770	708,990	604,414
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(248,568)	235,667	12,873
Cash and cash equivalents at beginning of period	248,596	12,929	56
Cash and cash equivalents at end of period	28	248,596	12,929
Cash paid (received) during the period for:
Interest - net of amount capitalized	87,094	89,077	89,402
Income taxes	17,594	2,792	17,010
Change in money pool receivable - net	4,601	6,580	(11,181)
Proceeds from Contributions from Parent	95,000	175,000	185,000
Proceeds from Issuance of Preferred Stock and Preference Stock	3,713	0	33,188
Change in money pool payable - net	79,594	0	(22,389)
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	106,814	99,131	99,120
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	198,067	184,429	212,170
Deferred income taxes, investment tax credits, and non-current taxes accrued	11,191	(455,732)	95
Changes in working capital:
Receivables	6,054	13,932	(23,382)
Accounts payable	23,973	(11,587)	18,204
Taxes accrued	(50,059)	69,145	19,247
Interest accrued	(1,008)	729	(1,302)
Other working capital accounts	25,096	(34,158)	15,879
Increase (Decrease) in Other Regulatory Assets	(143,417)	48,880	43,712
Increase (Decrease) in Regulatory Liabilities	40,884	140,965	130,949
Changes in pension and other postretirement liabilities	(49,308)	15,596	11,177
Other	253,910	119,032	138,304
Net cash flow provided by operating activities	201,211	(145,462)	300,141
INVESTING ACTIVITIES
Construction/capital expenditures	(100,474)	(193,857)	(166,695)
Allowance for equity funds used during construction	6,188	9,122	8,709
Nuclear fuel purchases	(45,180)	(94,991)	(18,170)
Decrease (increase) in other investments	(300)	0	0
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	0	5,459	0
Proceeds from nuclear decommissioning trust fund sales	1,022,170	418,943	500,384
Investment in nuclear decommissioning trust funds	(1,025,779)	(432,249)	(517,828)
Net cash flow used in investing activities	(193,392)	(206,443)	(119,553)
Proceeds from the issuance of:
Long-term debt	662,423	1,147,903	1,103,917
Retirement of long-term debt	(727,510)	(891,410)	(1,187,406)
Dividends paid:
Common stock	(96,000)	(80,653)	(124,250)
Net cash flow provided by financing activities	(161,087)	525,840	(207,739)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect	(153,268)	173,935	(27,151)
Cash and cash equivalents at beginning of period	242,469	68,534	95,685
Cash and cash equivalents at end of period	89,201	242,469	68,534
Cash paid (received) during the period for:
Interest - net of amount capitalized	39,340	35,061	21,052
Income taxes	54,959	384,329	2,284
Proceeds from sale of nuclear fuel	21,724	25,836	26,223
Change in money pool receivable - net	(71,741)	55,294	47,824
Proceeds from Contributions from Parent	$ 0	$ 350,000	$ 0

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash and cash equivalents:
Cash	$ 44,944	$ 128,851
Temporary cash investments	397,615	1,630,248
Total cash and cash equivalents	442,559	1,759,099	$ 425,722	$ 480,975
Accounts receivable:
Customer	786,866	833,478
Allowance for doubtful accounts	(68,608)	(117,794)
Other	231,843	135,208
Accrued unbilled revenues	420,255	434,835
Total accounts receivable	1,370,356	1,285,727
Deferred fuel costs	324,394	4,380
Fuel inventory - at average cost	154,575	172,934
Public Utilities, Inventory	1,041,515	962,185
Deferred nuclear refueling outage costs	133,422	179,150
Prepayments and other	156,774	196,424
TOTAL	3,623,595	4,559,899
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	5,514,016	7,253,215
Non-utility property - at cost (less accumulated depreciation)	357,576	343,328
Other	159,455	214,222
TOTAL	6,031,047	7,810,765
PROPERTY, PLANT, AND EQUIPMENT
Electric	64,263,250	59,696,443
Natural gas	658,989	610,768
Construction work in progress	1,511,966	2,012,030
Nuclear fuel	577,006	601,281
TOTAL PROPERTY, PLANT, AND EQUIPMENT	67,011,211	62,920,522
Less - accumulated depreciation and amortization	24,767,051	24,067,745
PROPERTY, PLANT, AND EQUIPMENT - NET	42,244,160	38,852,777
Regulatory assets:
Regulatory Assets, Noncurrent	6,613,256	6,076,549
Deferred Fuel Cost Non Current	240,953	240,422
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	54,186	76,289
Other	269,873	245,339
Deferred Costs and Other Assets	7,555,440	7,015,771
TOTAL ASSETS	59,454,242	58,239,212
CURRENT LIABILITIES
Currently maturing long-term debt	1,039,329	1,164,015
Short-term borrowings	1,201,177	1,627,489
Accounts payable	2,610,132	2,739,437
Customer deposits	395,184	401,512
Taxes accrued	419,828	441,011
Interest accrued	191,151	201,791
Deferred fuel costs	7,607	153,113
Pension and other postretirement liabilities	68,336	61,815
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	53,385	63,683
Other	204,613	206,640
TOTAL	6,190,742	7,060,506
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,706,797	4,361,772
Accumulated deferred investment tax credits	211,975	212,494
Regulatory liability for income taxes - net	1,255,692	1,521,757
Other regulatory liabilities	2,643,845	2,323,851
Decommissioning trust fund	4,757,084	6,469,452
Loss Contingency Accrual	157,122	242,835
Pension and other postretirement liabilities	1,949,325	2,853,013
Long-term debt	24,841,572	21,205,761
Deferred Credits and Other Liabilities	815,284	807,219
TOTAL	41,338,696	39,998,154
Commitments and Contingencies
Subsidiaries’ preferred stock without sinking fund	219,410	219,410
EQUITY
Common stock	2,720	2,700
Additional Paid in Capital, Common Stock	6,766,239	6,549,923
Retained Earnings (Accumulated Deficit)	10,240,552	9,897,182
Accumulated other comprehensive loss	(332,528)	(449,207)
Less - treasury stock, at cost (76,681,936 shares in 2013 and 76,945,239 shares in 2012)	5,039,699	5,074,456
Total common shareholders' equity	11,637,284	10,926,142
Total common shareholders' equity	11,705,394	10,961,142	10,258,675	8,844,305
Stockholders' Equity Attributable to Noncontrolling Interest	68,110	35,000
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	59,454,242	58,239,212
Preferred Stock, Value, Issued	$ 0	$ 0
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Authorized	1,000,000	0
Common Stock, Shares, Issued	271,965,510	270,035,180
Common Stock, Shares Authorized	499,000,000	500,000,000
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	$ 26	$ 26
Temporary cash investments	42,836	0
Total cash and cash equivalents	42,862	26	6,017	19,677
Restricted Investments, Current	1,999	3,364
Accounts receivable:
Customer	69,902	70,694
Allowance for doubtful accounts	(13,282)	(17,430)
Other	13,668	4,248
Accrued unbilled revenues	25,550	31,069
Total accounts receivable	169,984	90,962
Deferred fuel costs	0	2,130
Fuel inventory - at average cost	2,945	1,978
Public Utilities, Inventory	19,216	16,550
Prepayments and other	5,428	3,715
TOTAL	242,434	118,725
OTHER PROPERTY AND INVESTMENTS
Storm Reserve Escrow Account	0	83,038
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
TOTAL	1,016	84,054
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,976,202	1,821,638
Natural gas	373,983	348,024
Construction work in progress	22,199	12,460
TOTAL PROPERTY, PLANT, AND EQUIPMENT	2,372,384	2,182,122
Less - accumulated depreciation and amortization	774,309	740,796
PROPERTY, PLANT, AND EQUIPMENT - NET	1,598,075	1,441,326
Regulatory assets:
Regulatory Assets, Noncurrent	248,617	266,790
Deferred Fuel Cost Non Current	4,080	4,080
Other	56,101	23,931
Deferred Costs and Other Assets	308,798	294,801
TOTAL ASSETS	2,150,323	1,938,906
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,326	1,618
Associated companies accounts payable	45,057	54,234
Accounts payable	146,921	60,766
Customer deposits	28,539	27,912
Taxes accrued	4,385	4,700
Interest accrued	7,991	8,095
Deferred fuel costs	7,607	0
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	1,906	3,296
Other	6,204	5,462
TOTAL	249,936	166,083
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	365,384	338,714
Accumulated deferred investment tax credits	16,306	16,095
Regulatory liability for income taxes - net	40,589	55,675
Decommissioning trust fund	4,032	3,768
Loss Contingency Accrual	6,329	89,898
Long-term debt	777,254	629,704
Notes Payable, Related Parties, Noncurrent	9,585	10,911
Deferred Credits and Other Liabilities	42,193	21,141
TOTAL	1,261,672	1,165,906
Commitments and Contingencies
Members' Equity	638,715	606,917
EQUITY
Total common shareholders' equity	638,715	606,917	497,579	444,950
Members' Equity	638,715	606,917
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	2,150,323	1,938,906
Accounts Receivable, Related Parties, Current	74,146	2,381
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	195	1,303
Temporary cash investments	18,378	726,717
Total cash and cash equivalents	18,573	728,020	2,006	43,364
Accounts receivable:
Customer	355,265	317,905
Allowance for doubtful accounts	(29,231)	(45,693)
Other	36,674	41,760
Accrued unbilled revenues	174,768	178,840
Total accounts receivable	634,015	574,436
Deferred fuel costs	45,374	2,250
Fuel inventory - at average cost	42,958	50,680
Public Utilities, Inventory	485,325	437,933
Deferred nuclear refueling outage costs	39,582	48,407
Prepayments and other	44,187	36,813
TOTAL	1,310,014	1,878,539
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	2,114,523	1,794,042
Non-utility property - at cost (less accumulated depreciation)	337,247	323,110
Other	13,744	13,399
TOTAL	3,856,101	3,521,138
PROPERTY, PLANT, AND EQUIPMENT
Electric	28,055,038	25,619,789
Natural gas	285,006	262,744
Construction work in progress	847,924	667,281
Nuclear fuel	209,418	210,128
TOTAL PROPERTY, PLANT, AND EQUIPMENT	29,397,386	26,759,942
Less - accumulated depreciation and amortization	9,860,252	9,372,224
PROPERTY, PLANT, AND EQUIPMENT - NET	19,537,134	17,387,718
Regulatory assets:
Regulatory Assets, Noncurrent	2,776,666	1,726,066
Deferred Fuel Cost Non Current	168,122	168,122
Other	27,801	23,924
Deferred Costs and Other Assets	2,972,589	1,918,112
TOTAL ASSETS	27,675,838	24,705,507
CURRENT LIABILITIES
Currently maturing long-term debt	200,000	240,000
Associated companies accounts payable	183,172	103,148
Accounts payable	1,481,902	1,450,008
Customer deposits	150,697	152,612
Taxes accrued	64,248	42,617
Interest accrued	93,052	92,249
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	24,291	31,138
Other	68,995	62,968
TOTAL	2,266,357	2,174,740
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,433,854	2,138,522
Accumulated deferred investment tax credits	102,588	107,317
Regulatory liability for income taxes - net	313,693	447,628
Other regulatory liabilities	1,042,597	918,293
Decommissioning trust fund	1,653,198	1,573,307
Loss Contingency Accrual	24,490	24,939
Pension and other postretirement liabilities	528,213	692,728
Long-term debt	10,714,346	8,787,451
Deferred Credits and Other Liabilities	415,930	382,894
TOTAL	17,228,909	15,073,079
Commitments and Contingencies
Members' Equity	8,172,294	7,453,361
EQUITY
Accumulated other comprehensive loss	8,278	4,327
Total common shareholders' equity	8,180,572	7,457,688	6,397,118	5,902,918
Members' Equity	8,172,294	7,453,361
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	27,675,838	24,705,507
Accounts Receivable, Related Parties, Current	96,539	81,624
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	8,155	24,108
Temporary cash investments	4,760	168,020
Total cash and cash equivalents	12,915	192,128	3,519	119
Accounts receivable:
Customer	154,412	183,719
Allowance for doubtful accounts	(13,072)	(18,334)
Other	51,064	35,845
Accrued unbilled revenues	101,663	109,000
Total accounts receivable	323,654	344,446
Deferred fuel costs	108,862	0
Fuel inventory - at average cost	50,892	43,811
Public Utilities, Inventory	247,980	237,640
Deferred nuclear refueling outage costs	65,318	32,692
Prepayments and other	14,863	13,296
TOTAL	824,484	864,013
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,438,416	1,273,921
Other	947	341
TOTAL	1,439,363	1,274,262
PROPERTY, PLANT, AND EQUIPMENT
Electric	13,578,297	12,905,322
Construction work in progress	241,127	234,213
Nuclear fuel	182,055	163,044
TOTAL PROPERTY, PLANT, AND EQUIPMENT	14,001,479	13,302,579
Less - accumulated depreciation and amortization	5,472,296	5,255,355
PROPERTY, PLANT, AND EQUIPMENT - NET	8,529,183	8,047,224
Regulatory assets:
Regulatory Assets, Noncurrent	1,689,678	1,832,384
Deferred Fuel Cost Non Current	68,751	68,220
Other	13,660	14,028
Deferred Costs and Other Assets	1,772,089	1,914,632
TOTAL ASSETS	12,565,119	12,100,131
CURRENT LIABILITIES
Currently maturing long-term debt	0	485,000
Associated companies accounts payable	217,310	59,448
Accounts payable	190,476	208,591
Customer deposits	92,511	98,506
Taxes accrued	89,590	81,837
Interest accrued	17,108	22,745
Deferred fuel costs	0	53,065
Other	38,901	40,628
TOTAL	645,896	1,049,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,416,201	1,286,123
Accumulated deferred investment tax credits	29,299	30,500
Regulatory liability for income taxes - net	431,655	467,031
Other regulatory liabilities	743,314	686,872
Decommissioning trust fund	1,390,410	1,314,160
Loss Contingency Accrual	77,084	70,169
Pension and other postretirement liabilities	185,789	361,682
Long-term debt	3,958,862	3,482,507
Deferred Credits and Other Liabilities	110,754	75,098
TOTAL	8,343,368	7,774,142
Commitments and Contingencies
Members' Equity	3,542,745	3,276,169
Members' Equity Attributable to Noncontrolling Interest	33,110	0
EQUITY
Total common shareholders' equity	3,575,855	3,276,169	3,125,937	2,983,103
Members' Equity	3,542,745	3,276,169
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	12,565,119	12,100,131
Accounts Receivable, Related Parties, Current	$ 29,587	$ 34,216
Preferred Stock, Shares Authorized	0	0
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	$ 29	$ 11
Temporary cash investments	47,598	7
Total cash and cash equivalents	47,627	18	51,601	36,954
Accounts receivable:
Customer	84,048	105,732
Allowance for doubtful accounts	(7,209)	(19,527)
Other	14,609	11,821
Accrued unbilled revenues	56,034	59,514
Total accounts receivable	190,476	160,280
Deferred fuel costs	121,878	0
Fuel inventory - at average cost	10,311	17,117
Public Utilities, Inventory	69,639	59,542
Prepayments and other	6,394	4,876
TOTAL	446,325	241,833
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,527	4,543
TOTAL	53,413	69,178
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,613,109	6,084,730
Construction work in progress	95,452	134,854
TOTAL PROPERTY, PLANT, AND EQUIPMENT	6,708,561	6,219,584
Less - accumulated depreciation and amortization	2,127,590	2,005,087
PROPERTY, PLANT, AND EQUIPMENT - NET	4,580,971	4,214,497
Regulatory assets:
Regulatory Assets, Noncurrent	462,432	467,341
Other	14,248	14,413
Deferred Costs and Other Assets	476,680	481,754
TOTAL ASSETS	5,557,389	5,007,262
CURRENT LIABILITIES
Currently maturing long-term debt	0	0
Associated companies accounts payable	42,929	61,727
Accounts payable	113,000	117,629
Customer deposits	86,167	86,200
Taxes accrued	106,273	108,084
Interest accrued	17,283	20,889
Deferred fuel costs	0	14,691
Other	36,731	34,270
TOTAL	402,383	443,490
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	720,097	646,674
Accumulated deferred investment tax credits	10,913	9,062
Regulatory liability for income taxes - net	212,445	224,000
Other regulatory liabilities	49,313	15,828
Decommissioning trust fund	10,315	9,762
Loss Contingency Accrual	38,028	46,504
Pension and other postretirement liabilities	59,065	110,901
Long-term debt	2,179,989	1,780,577
Deferred Credits and Other Liabilities	35,273	47,730
TOTAL	3,315,438	2,891,038
Commitments and Contingencies
Members' Equity	1,839,568	1,672,734
EQUITY
Total common shareholders' equity	1,839,568	1,672,734	1,542,151	1,292,226
Members' Equity	1,839,568	1,672,734
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	5,557,389	5,007,262
Accounts Receivable, Related Parties, Current	42,994	2,740
Escrow accounts	48,886	64,635
Entergy Texas [Member]
Cash and cash equivalents:
Cash	28	26
Temporary cash investments	0	248,570
Total cash and cash equivalents	28	248,596	12,929	56
Restricted Investments, Current	26,629	36,233
Accounts receivable:
Customer	83,797	103,221
Allowance for doubtful accounts	(5,814)	(16,810)
Other	13,404	11,780
Accrued unbilled revenues	62,241	56,411
Total accounts receivable	185,348	173,494
Deferred fuel costs	48,280	0
Fuel inventory - at average cost	42,712	53,531
Public Utilities, Inventory	72,884	56,227
Prepayments and other	17,515	20,165
TOTAL	393,396	588,246
Equity Method Investments	300	349
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	18,128	19,889
TOTAL	18,804	20,614
PROPERTY, PLANT, AND EQUIPMENT
Electric	7,181,567	6,007,687
Construction work in progress	183,965	879,908
TOTAL PROPERTY, PLANT, AND EQUIPMENT	7,365,532	6,887,595
Less - accumulated depreciation and amortization	2,049,750	1,864,494
PROPERTY, PLANT, AND EQUIPMENT - NET	5,315,782	5,023,101
Regulatory assets:
Regulatory Assets, Noncurrent	421,333	524,713
Other	112,096	70,397
Deferred Costs and Other Assets	533,429	595,110
TOTAL ASSETS	6,261,411	6,227,071
CURRENT LIABILITIES
Currently maturing long-term debt	0	200,000
Associated companies accounts payable	142,929	55,944
Accounts payable	164,981	350,947
Customer deposits	37,271	36,282
Taxes accrued	49,018	52,438
Interest accrued	19,002	20,856
Deferred fuel costs	0	85,356
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	27,188	29,249
Other	16,120	12,370
TOTAL	456,509	843,442
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	692,496	639,422
Accumulated deferred investment tax credits	9,325	9,942
Regulatory liability for income taxes - net	144,145	175,594
Other regulatory liabilities	37,060	32,297
Decommissioning trust fund	8,520	8,063
Loss Contingency Accrual	8,242	8,382
Long-term debt	2,354,148	2,293,708
Deferred Credits and Other Liabilities	67,760	58,643
TOTAL	3,321,696	3,226,051
Commitments and Contingencies
EQUITY
Common stock	49,452	49,452
Additional Paid in Capital, Common Stock	1,050,125	955,162
Retained Earnings (Accumulated Deficit)	1,344,879	1,117,964
Total common shareholders' equity	2,444,456	2,122,578
Total common shareholders' equity	2,483,206	2,157,578	1,799,407	1,422,402
Stockholders' Equity Attributable to Noncontrolling Interest	38,750	35,000
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	6,261,411	6,227,071
Accounts Receivable, Related Parties, Current	$ 31,720	$ 18,892
Preferred Stock, Shares Authorized	1,550,000	1,400,000
Common Stock, Shares, Issued	46,525,000	46,525,000
Common Stock, Shares Authorized	200,000,000	200,000,000
System Energy [Member]
Cash and cash equivalents:
Cash	$ 87	$ 26,086
Temporary cash investments	89,114	216,383
Total cash and cash equivalents	89,201	242,469	68,534	95,685
Accounts receivable:
Other	7,003	2,550
Total accounts receivable	125,980	60,293
Public Utilities, Inventory	127,093	123,006
Deferred nuclear refueling outage costs	10,123	34,459
Prepayments and other	1,870	6,864
TOTAL	354,267	467,091
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,385,254	1,215,868
TOTAL	1,385,254	1,215,868
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,362,494	5,309,458
Construction work in progress	97,968	59,831
Nuclear fuel	171,438	175,005
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,631,900	5,544,294
Less - accumulated depreciation and amortization	3,396,136	3,355,367
PROPERTY, PLANT, AND EQUIPMENT - NET	2,235,764	2,188,927
Regulatory assets:
Regulatory Assets, Noncurrent	395,546	538,963
Other	1,793	3,119
Deferred Costs and Other Assets	397,339	542,082
TOTAL ASSETS	4,372,624	4,413,968
CURRENT LIABILITIES
Currently maturing long-term debt	50,329	100,015
Associated companies accounts payable	23,682	15,309
Accounts payable	62,573	41,313
Taxes accrued	32,918	82,977
Interest accrued	11,714	12,722
Other	4,101	4,248
TOTAL	185,317	256,584
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	382,931	359,835
Accumulated deferred investment tax credits	43,003	38,902
Regulatory liability for income taxes - net	113,165	151,829
Other regulatory liabilities	744,944	665,396
Decommissioning trust fund	1,007,603	968,910
Pension and other postretirement liabilities	76,104	125,412
Long-term debt	690,967	705,259
Deferred Credits and Other Liabilities	37,230	61,295
TOTAL	3,095,947	3,076,838
Commitments and Contingencies
EQUITY
Common stock	951,850	951,850
Retained Earnings (Accumulated Deficit)	139,510	128,696
Total common shareholders' equity	1,091,360	1,080,546	$ 712,068	$ 737,198
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,372,624	4,413,968
Accounts Receivable, Related Parties, Current	$ 118,977	$ 57,743
Common Stock, Shares, Issued	789,350	789,350
Common Stock, Shares Authorized	1,000,000	1,000,000

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Securitization property	$ 49,579	$ 119,238
Securitization bonds	$ 83,639	$ 174,635
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	499,000,000	500,000,000
Common stock, shares issued	271,965,510	270,035,180
Treasury stock, shares	69,312,326	69,790,346
Entergy Louisiana [Member]
Securitization property	$ 0	$ 5,088
Securitization bonds	0	10,278
Entergy New Orleans [Member]
Securitization property	25,761	35,559
Long-term Transition Bond	29,661	41,291
Entergy Texas [Member]
Securitization property	23,818	78,590
Securitization bonds	$ 53,979	$ 123,066
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
System Energy [Member]
Common stock, shares authorized	1,000,000	1,000,000
Common stock, shares issued	789,350	789,350
Common Stock, Shares, Outstanding	789,350	789,350

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total	Common Stock [Member]	Treasury Stock [Member]	Paid In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]	Subsidiaries Preferred Stock and Noncontrolling Interest	Entergy Arkansas [Member]	Entergy Arkansas [Member]Member's Equity [Member]	Entergy Arkansas [Member]Noncontrolling Interest	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy Mississippi [Member]	Entergy New Orleans [Member]	Entergy Texas [Member]	Entergy Texas [Member]Subsidiaries' Preferred Stock [Member]	Entergy Texas [Member]Common Stock [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	System Energy [Member]	System Energy [Member]Common Stock [Member]	System Energy [Member]Retained Earnings [Member]	Entergy Corporation [Member]
Total common shareholders' equity	$ 8,844,305	$ 2,616	$ (5,273,719)	$ 5,951,431	$ 8,721,150	$ (557,173)	$ 0	$ 2,983,103	$ 2,983,103	$ 0	$ 5,902,918	$ 5,909,071	$ (6,153)	$ 1,292,226	$ 444,950	$ 1,422,402	$ 0	$ 49,452	$ 596,994	$ 775,956	$ 737,198	$ 601,850	$ 135,348
Consolidated net income	1,258,244	0	0	0		0	17,018	262,964	262,964	0	691,537	691,537	0	119,925	52,629	159,397	0	0	0	159,397	99,120	0	99,120
Net Income (Loss) Attributable to Parent	1,241,226				1,241,226
Proceeds from Contributions from Parent											0			130,000	0	185,000	0	0	185,000	0	0
Other comprehensive income (loss)	117,059	0	0	0	0	117,059	0				10,715	0	10,715
Stock Issued During Period, Value, New Issues	(607,650)	(84)	0	(607,566)	0	0	0									(33,188)	(35,000)	0	1,812	0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	(7)	0	0	(7)	0	0	0
Payments for Repurchase of Preferred Stock and Preference Stock	(50,000)
Common stock issuances related to stock plans	125,015	0	119,569	5,446	0	0	0
Dividends, Common Stock, Cash	(711,573)	0	0	0	(711,573)	0	0	(115,000)	(115,000)	0	(208,000)	(208,000)	0								(124,250)	0	(124,250)
Proceeds from Noncontrolling Interests	0							0
Preferred Stock Redemptions	35,000	0	0	0	0	0	35,000
Other								(5,130)	(5,130)	0	(52)	(52)	0
Dividends, Preferred Stock, Cash	(17,018)	0	0	0	0	0	(17,018)									(580)	0	0	0	(580)				$ (16,000)
Total common shareholders' equity	10,258,675	2,700	(5,154,150)	6,564,436	9,257,609	(446,920)	35,000	3,125,937	3,125,937	0	6,397,118	6,392,556	4,562	1,542,151	497,579	1,799,407	35,000	49,452	780,182	934,773	712,068	601,850	110,218
Consolidated net income	1,406,653	0	0	0		0	18,319	245,232	245,232	0	1,082,352	1,082,352	0	140,583	49,338	215,073	0	0	0	215,073	99,131	0	99,131
Net Income (Loss) Attributable to Parent	1,388,334				1,388,334
Proceeds from Contributions from Parent											0			0	60,000	175,000	0	0	175,000	0	350,000	350,000	0
Other comprehensive income (loss)	(2,287)	0	0	0	0	(2,287)	0				(235)	0	(235)
Payments for Repurchase of Preferred Stock and Preference Stock	0
Common stock issuances related to stock plans	65,181	0	79,694	(14,513)	0	0	0
Dividends, Common Stock, Cash	(748,342)	0	0	0	(748,342)	0	0	(95,000)	(95,000)	0	(21,500)	(21,500)	0	(10,000)		(30,000)	0	0	0	(30,000)	(80,653)	0	(80,653)
Proceeds from Noncontrolling Interests	0							0
Other											(47)	(47)	0			(20)	0	0	(20)	0
Dividends, Preferred Stock, Cash	(18,319)	0	0	0	0	0	(18,319)									(1,882)	0	0	0	(1,882)				(16,000)
Total common shareholders' equity	10,961,142	2,700	(5,074,456)	6,549,923	9,897,182	(449,207)	35,000	3,276,169	3,276,169	0	7,457,688	7,453,361	4,327	1,672,734	606,917	2,157,578	35,000	49,452	955,162	1,117,964	1,080,546	951,850	128,696
Consolidated net income	1,118,719	0	0	0		0	227	298,484	316,576	(18,092)	653,984	653,984	0	166,834	31,798	228,824	0	0	0	228,824	106,814	0	106,814
Net Income (Loss) Attributable to Parent	1,118,492				1,118,492
Proceeds from Contributions from Parent											125,000	125,000	0	0	0	95,000	0	0	95,000	0	0
Other comprehensive income (loss)	116,679	0	0	0	0	116,679	0				3,951	0	3,951
Stock Issued During Period, Value, New Issues	(204,214)	(20)	0	(204,194)	0	0	0									(3,713)	(3,750)	0	37	0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	(3,438)	0	0	(3,438)	0	0	0
Payments for Repurchase of Preferred Stock and Preference Stock	0
Common stock issuances related to stock plans	50,317	0	34,757	15,560	0	0	0
Dividends, Common Stock, Cash	(775,122)	0	0	0	(775,122)	0	0	(50,000)	(50,000)	0	(60,000)	(60,000)	0								(96,000)	0	(96,000)
Proceeds from Noncontrolling Interests	51,202	0	0	0	0	0	51,202	51,202	0	51,202
Other											(51)	(51)	0
Dividends, Preferred Stock, Cash	(18,319)	0	0	0	0	0	(18,319)									(1,909)	0	0	0	(1,909)				$ (16,000)
Total common shareholders' equity	$ 11,705,394	$ 2,720	$ (5,039,699)	$ 6,766,239	$ 10,240,552	$ (332,528)	$ 68,110	$ 3,575,855	$ 3,542,745	$ 33,110	$ 8,180,572	$ 8,172,294	$ 8,278	$ 1,839,568	$ 638,715	$ 2,483,206	$ 38,750	$ 49,452	$ 1,050,125	$ 1,344,879	$ 1,091,360	$ 951,850	$ 139,510

Consolidated Statements Of Ch_2

Consolidated Statements Of Changes In Equity (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Preferred dividends on subsidiaries' preferred stock	$ 18,319	$ 18,319	$ 17,018
Entergy Corporation [Member]
Preferred dividends on subsidiaries' preferred stock	$ 16,000	$ 16,000	$ 16,000

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
Entergy Arkansas [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
Entergy Louisiana [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
Entergy Mississippi [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
Entergy New Orleans [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
Entergy Texas [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra
System Energy [Member]
Summary Of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries also maintain accounts in accordance with FERC and other regulatory guidelines. Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020. As of December 31, 2021, construction expenditures included in accounts payable are $35.6 million for Entergy Arkansas, $507.9 million for Entergy Louisiana, $26.5 million for Entergy Mississippi, $73.1 million for Entergy Texas, and $23.4 million for System Energy. As of December 31, 2020, construction expenditures included in accounts payable are $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy. Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements. Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts. Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. The assessment of whether an investment in an available-for-sale debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). Effective January 1, 2020, with the adoption of ASU 2016-13, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an expected credit loss is realized, the individual security comprising the loss is written off against this allowance. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 16 to the financial statements for details on the decommissioning trust funds. Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and distributions, between Entergy Arkansas and the tax equity investor. Once the tax equity investor reaches its target return in the hypothetical liquidation, the remaining proceeds are primarily allocated to Entergy Arkansas. This allocation may result in fluctuations of income on a periodic basis that differ significantly from what would otherwise be recognized if the earnings were allocated under the relative ownership percentages between Entergy Arkansas and the tax equity investor. Entergy Arkansas has determined these differences are primarily due to timing, and the APSC has approved that, for purposes of ratemaking, Entergy Arkansas reflect its interest in the partnership using its relative ownership percentage and disregard the effects of the HLBV method of accounting. Because of this, Entergy Arkansas recorded a regulatory liability of $18.1 million in 2021 for the difference between the earnings allocated to it under the HLBV method of accounting and the earnings that would have been allocated to it under its respective ownership percentage in the partnership. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants. River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Tra

Rate And Regulatory Matters

Rate And Regulatory Matters	12 Months Ended
	Dec. 31, 2021
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
Entergy Arkansas [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
Entergy Louisiana [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
Entergy Mississippi [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
Entergy New Orleans [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
Entergy Texas [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi
System Energy [Member]
Rate And Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. In addition to the regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2021 and 2020: Other Regulatory Assets Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5 Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4 Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1 Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3 Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8 Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7 System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0 (a) Does not earn a return on investment, but is offset by related liabilities. (b) Does not earn a return on investment. Hurricane Ida In August 2021, Hurricane Ida caused extensive damage to the Entergy distribution and, to a lesser extent, transmission systems across Louisiana resulting in widespread power outages. Total restoration costs for the repair and/or replacement of the electrical system damaged by Hurricane Ida for Entergy Louisiana and Entergy New Orleans are currently estimated to be approximately $2.7 billion. Also, Utility revenues in 2021 were adversely affected by extended power outages resulting from the hurricane. Entergy has recorded accounts payable for the estimated costs incurred that were necessary to return customers to service. Entergy recorded corresponding regulatory assets of approximately $1.1 billion, including $1 billion at Entergy Louisiana and $80 million at Entergy New Orleans, and construction work in progress of approximately $1.6 billion, including $1.5 billion at Entergy Louisiana and $120 million at Entergy New Orleans. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service area because management believes that recovery through some form of regulatory mechanism is probable. There are well-established mechanisms and precedent for addressing these catastrophic events and providing for recovery of prudently incurred storm costs in accordance with applicable regulatory and legal principles. Because Entergy has not gone through the regulatory process regarding these storm costs, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery. Entergy is considering all available avenues to recover storm-related costs from Hurricane Ida, including federal government assistance and securitization financing. In September 2021, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments in connection with the issuance of approximately $1 billion of shorter-term mortgage bonds to provide interim financing for restoration costs associated with Hurricane Ida, which bonds were issued in October 2021. Also in September 2021, as discussed below in “ Storm Cost Filings with Retail Regulators - Entergy Louisiana - Hurricane Laura, Hurricane Delta, Hurricane Zeta, Winter Storm Uri, and Hurricane Ida ,” Entergy Louisiana sought approval for the creation and funding of a $1 billion restricted escrow account for Hurricane Ida restoration costs, subject to a subsequent prudence review. In September 2021, Entergy New Orleans withdrew $39 million from its funded storm reserves. Storm cost recovery or financing will be subject to review by applicable regulatory authorities. In February 2022, Entergy New Orleans filed with the City Council a securitization application requesting that the City Council review Entergy New Orleans’s storm reserve and increase the storm reserve funding level to $150 million, to be funded through securitization. Other Regulatory Liabilities Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9 Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9 Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3 Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8 Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3 System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4 (a) Offset by related asset. (b) As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21% effective January 2018, the Vidalia purchased power agreement regulatory liability was reduced by $30.5 million and the Louisiana Act 55 financing savings obligation regulatory liabilities were reduced by $25 million, with corresponding increases to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Regulatory activity regarding the Tax Cuts and Jobs Act See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Entergy Arkansas Consistent with its previously stated intent to return unprotected excess accumulated deferred income taxes to customers as expeditiously as possible, Entergy Arkansas initiated a tariff proceeding in February 2018 proposing to establish a tax adjustment rider to provide retail customers with certain tax benefits of $467 million associated with the Tax Act. For the residential customer class, unprotected excess accumulated deferred income taxes were returned to customers over a 21-month period from April 2018 through December 2019. For all other customer classes, unprotected excess accumulated deferred income taxes were returned to customers over a nine-month period from April 2018 through December 2018. A true-up provision also was included in the rider, with any over- or under-returned unprotected excess accumulated deferred income taxes credited or billed to customers during the billing month of January 2020, with any residual amounts of over- or under-returned unprotected excess accumulated deferred income taxes to be flowed through Entergy Arkansas’s energy cost recovery rider. In March 2018 the APSC approved the tax adjustment rider effective with the first billing cycle of April 2018. As discussed below, in July 2018, Entergy Arkansas made its formula rate plan filing to set its formula rate for the 2019 calendar year. A hearing was held in May 2018 regarding the APSC’s inquiries into the effects of the Tax Act, including Entergy Arkansas’s proposal to utilize its formula rate plan rider for its customers to realize the remaining benefits of the Tax Act. Entergy Arkansas’s formula rate plan rider included a netting adjustment that compared actual annual results to the allowed rate of return on common equity. In July 2018 the APSC issued an order agreeing with Entergy Arkansas’s proposal to have the effects of the Tax Act on current income tax expense flow through Entergy Arkansas’s formula rate plan rider and with Entergy Arkansas’s treatment of protected and unprotected excess accumulated deferred income taxes. The APSC also directed Entergy Arkansas to submit in the tax adjustment rider proceeding, discussed above, the adjustments to all other riders affected by the Tax Act and to include an amendment for a true up mechanism where a rider affected by the Tax Act does not already contain a true-up mechanism. Pursuant to a 2018 settlement agreement in Entergy Arkansas’s formula rate plan proceeding, Entergy Arkansas also removed the net operating loss accumulated deferred income tax asset caused by the Tax Act from Entergy Arkansas’s tax adjustment rider. Entergy Arkansas’s compliance tariff filings were accepted by the APSC in October 2018. In February 2021, pursuant to its 2020 formula rate plan evaluation report settlement, Entergy Arkansas flowed $5.6 million in credits to customers through the tax adjustment rider based on the outcome of certain federal tax positions and a decrease in the state tax rate. Entergy Louisiana In an electric formula rate plan settlement approved by the LPSC in April 2018 the parties agreed that Entergy Louisiana would return to customers one-half of its eligible unprotected excess deferred income taxes from May 2018 through December 2018 and return to customers the other half from January 2019 through August 2022. In addition, the settlement provided that in order to flow back to customers certain other tax benefits created by the Tax Act, Entergy Louisiana established a regulatory liability effective January 1, 2018 in the amount of $9.1 million per month to reflect these tax benefits already included in retail rates until new base rates under the formula rate plan were established in September 2018, and this regulatory liability was returned to customers over the September 2018 through August 2019 formula rate plan rate-effective period. The LPSC staff and intervenors in the settlement reserved the right to obtain data from Entergy Louisiana to confirm the determination of excess accumulated deferred income taxes resulting from the Tax Act and the analysis thereof as part of the formula rate plan review proceeding for the 2017 test year filing which, as discussed below, Entergy Louisiana filed in June 2018. Entergy New Orleans After enactment of the Tax Act the City Council passed a resolution ordering Entergy New Orleans to, effective January 1, 2018, record deferred regulatory liabilities to account for the Tax Act’s effect on Entergy New Orleans’s revenue requirement and to make a filing by mid-March 2018 regarding the Tax Act’s effects on Entergy New Orleans’s operating income and rate base and potential mechanisms for customers to receive benefits of the Tax Act. The City Council’s resolution also directed Entergy New Orleans to request that Entergy Services file with the FERC for revisions of the Unit Power Sales Agreement and MSS-4 replacement tariffs to address the return of excess accumulated deferred income taxes. Entergy submitted filings of this type to the FERC. In March 2018, Entergy New Orleans filed its response to the resolution stating that the Tax Act reduced income tax expense from what was then reflected in rates by approximately $8.2 million annually for electric operations and by approximately $1.3 million annually for gas operations. In the filing, Entergy New Orleans proposed to return to customers from June 2018 through August 2019 the benefits of the reduction in income tax expense and its unprotected excess accumulated deferred income taxes through a combination of bill credits and investments in energy efficiency programs, grid modernization, and Smart City projects. Entergy New Orleans submitted supplemental information in April 2018 and May 2018. Shortly thereafter, Entergy New Orleans and the City Council’s advisors reached an agreement in principle that provides for benefits that will be realized by Entergy New Orleans customers through bill credits that started in July 2018 and offsets to future investments in energy efficiency programs, grid modernization, and Smart City projects, as well as additional benefits related to the filings made at the FERC. The agreement in principle was approved by the City Council in June 2018. Entergy Texas After enactment of the Tax Act the PUCT issued an order requiring most utilities, including Entergy Texas, beginning January 25, 2018, to record a regulatory liability for the difference between revenues collected under existing rates and revenues that would have been collected had existing rates been set using the new federal income tax rates and also for the balance of excess accumulated deferred income taxes. Entergy Texas had previously provided information to the PUCT staff and stated that it expected the PUCT to address the lower tax expense as part of Entergy Texas’s rate case expected to be filed in May 2018. In May 2018, Entergy Texas filed its 2018 base rate case with the PUCT. Entergy Texas’s proposed rates and revenues reflected the inclusion of the federal income tax reductions due to the Tax Act. The PUCT issued an order in December 2018 establishing that 1) $25 million be credited to customers through a rider to reflect the lower federal income tax rate applicable to Entergy Texas from January 2018 through the date new rates were implemented, 2) $242.5 million of protected excess accumulated deferred income taxes be returned to customers through base rates under the average rate assumption method over the lives of the associated assets, and 3) $185.2 million of unprotected excess accumulated deferred income taxes be returned to customers through a rider. The unprotected excess accumulated deferred income taxes rider includes carrying charges and is in effect over a period of 12 months for larger customers and over a period of four years for other customers. System Energy In a filing made with the FERC in March 2018, System Energy proposed revisions to the Unit Power Sales Agreement to reflect the effects of the Tax Act. In the filing System Energy proposed to return identified quantities of unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures. Settlement discussions were terminated in April 2019, and a hearing was held in March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement challenged the treatment and amount of excess accumulated deferred income tax liabilities associated with uncertain tax positions related to nuclear decommissioning. In July 2020 the presiding ALJ in the proceeding issued an initial decision finding that there is an additional $147 million in unprotected excess accumulated deferred income taxes related to System Energy’s uncertain decommissioning tax deduction. The initial decision determined that System Energy should have included the $147 million in its March 2018 filing. System Energy had not included credits related to the effect of the Tax Act on the uncertain decommissioning tax position because it was uncertain whether the IRS would allow the deduction. The initial decision rejected both System Energy’s alternative argument that any crediting should occur over a ten-year period and the retail regulators’ argument that any crediting should occur over a two-year period. Instead, the initial decision concluded that System Energy should credit the additional unprotected excess accumulated deferred income taxes in a single lump sum revenue requirement reduction following a FERC order addressing the initial decision. The ALJ initial decision is an interim step in the FERC litigation process. In September 2020, System Energy filed a brief on exceptions with the FERC, re-urging its positions and requesting the reversal of the ALJ’s initial decision. In December 2020, the LPSC, APSC, MPSC, City Council, and FERC trial staff filed briefs opposing exceptions. The FERC will review the case and issue an order in the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Credits, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. As discussed below in “ Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue ,” in September 2020 the IRS issued a Notice of Proposed Adjustment (NOPA) and Entergy executed it. In September 2020, System Energy filed a motion to lodge the NOPA into the record in the FERC proceeding. In October 2020 the LPSC, APSC, MPSC, City Council, and FERC trial staff filed oppositions to System Energy’s motion. As a result of the NOPA, System Energy filed, in October 2020, a new Federal Power Act section 205 filing at the FERC to credit the excess accumulated deferred income taxes resulting from the decommissioning uncertain tax position. System Energy proposes to credit the entire amount of the excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position by issuing a one-time credit of $17.8 million. In November 2020, the LPSC, APSC, MPSC, and City Council filed a protest to the filing, and System Energy responded. In November 2020 the IRS issued the Revenue Agent’s Report (RAR) for the 2014-2015 tax years and in December 2020 Entergy executed it. In December 2020, System Energy filed a motion to lodge the RAR into the record in the FERC proceeding addressing the Tax Cuts and Jobs Act. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’s motion. As a result of the RAR, in December 2020, System Energy also filed an amendment to its Federal Power Act section 205 filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendment proposed the inclusion of the RAR as support for the filing. In December 2020, the LPSC, APSC, and City Council filed a protest in response to the amendment, reiterating objections to the filing to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. In November 2020, System Energy filed a motion to vacate the ALJ’s decision, arguing that it had been overtaken by changed circumstances because of the IRS’s determination resulting from the NOPA and RAR. In January 2021 the LPSC, APSC, MPSC, and City Council filed a joint answer opposing System Energy’s motion, and the FERC trial staff also filed an answer opposing System Energy’ s motion. Additional responsive pleadings were filed in February and March 2021. There is no formal deadline for FERC to rule on the motion. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Arkansas Energy Cost Recovery Rider Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In January 2014, Entergy Arkansas filed a motion with the APSC relating to its upcoming energy cost rate redetermination filing that was made in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy Arkansas to exclude from the redetermination of its 2014 energy cost rate $65.9 million of incremental fuel and replacement energy costs incurred in 2013 as a result of the ANO stator incident. Entergy Arkansas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later period after more information was available regardi

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825) Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions. Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483) Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns. Entergy evaluates the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate character will be generated to realize the benefits of existing deferred tax assets. When the evaluation indicates that Entergy will not be able to realize the existing benefits, a valuation allowance is recorded to reduce deferred tax assets to the realizable amount. Because it is more likely than not that the benefits from certain state net operating losses and other deferred tax assets will not be utilized, valuation allowances totaling $325 million as of December 31, 2021 and $329 million as of December 31, 2020 have been provided on the deferred tax assets related to federal and state jurisdictions in which Entergy does not currently expect to be able to utilize certain separate company tax return attributes, preventing realization of such deferred tax assets. As a result of incurring costs related to Hurricane Ida restoration, certain Utility operating companies are entitled to an accelerated tax deduction which generated a taxable loss in various taxing jurisdictions. This accelerated deduction has impaired the realizability of a limited term carryover tax attribute. Accordingly, the impairment contributed to the activity reflected for the valuation allowance disclosed above. Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835) The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025 As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers. Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns The balances of unrecognized tax benefits include $2,256 million, $2,208 million, and $2,421 million as of December 31, 2021, 2020, and 2019, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3,504 million, $3,491 million, and $4,962 million as of December 31, 2021, 2020, and 2019, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period. Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2021, 2020, and 2019 accrued balance for the possible payment of interest is approximately $52 million, $44 million, and $48 million, respectively. Interest (net-of-tax) of $8 million, ($4) million, and $4 million was recorded in 2021, 2020, and 2019, respectively. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods ” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $— Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5 The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2021, 2020, and 2019. Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3 Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2016. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2014-2015 IRS Audit The IRS completed its examination of the 2014 and 2015 tax years and issued its 2014-2015 RAR in November 2020. Entergy agreed to all proposed adjustments contained in the RAR. Entergy and the Registrant Subsidiaries recorded the effects of the adjustments associated with the audit in 2020. In October 2015 two of Entergy’s Louisiana utilities, Entergy Gulf States Louisiana and Entergy Louisiana, combined their businesses into a legal entity which is identified as Entergy Louisiana herein. The structure of the business combination required Entergy to recognize a gain for income tax purposes which resulted in an increase in the tax basis of the assets for Entergy Louisiana. This resulted in recognition in 2015 of a $334 million permanent difference and income tax benefit, net of the uncertain tax position recorded on the transaction. Primarily related to resolution of the business combination issues, completion of the 2014-2015 IRS audit in 2020 resulted in a $230 million reduction to deferred income tax expense for Entergy. This reduction to deferred income tax expense includes: Entergy Louisiana reversing its provision for uncertain tax position with respect to the business combination, which resulted in a reduction to deferred income tax expense of $383 million; Entergy Corporation recording an increase to deferred tax expense of $61 million and Entergy Wholesale Commodities recording an increase to deferred tax expense of $105 million from the re-measurement of deferred tax assets associated with the resolved uncertain tax position; and miscellaneous other individually insignificant benefits totaling $13 million. The completion of the 2014-2015 tax audit also resulted in a $31 million reduction to income tax expense associated with Entergy Louisiana’s method of accounting related to the adoption of tangible property regulations. As a result of the settlement of the tangible property regulation tax position, Entergy Louisiana was required to record a $33 million ($24 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to a prior regulatory settlement. Finally, upon completion of the 2014-2015 tax audit, Entergy New Orleans recorded a reduction to income tax expense of $8 million associated with claims for mark-to-market deductions. In the first quarter 2020, Entergy and the IRS agreed on the treatment of funds received by Entergy Louisiana in conjunction with the Act 55 financing of Hurricane Isaac storm costs, which resulted in a net reduction of income tax expense of approximately $32 million. As a result of the settlement, the position was partially sustained, and Entergy Louisiana recorded a reduction of income tax expense of approximately $58 million primarily due to the reversal of a provision for uncertain tax positions in excess of the agreed-upon settlement. As a result of the IRS settlement, Entergy Louisiana recorded a $29 million ($21 million net-of-tax) regulatory charge and a corresponding regulatory liability to reflect its obligation to customers pursuant to the LPSC Hurricane Isaac Act 55 financing order. Additional effects of the completion of the 2014-2015 IRS tax audit are discussed below within Tax Accounting Methods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. TCJA also limited the deduction for net business interest expense to 30 percent of adjusted taxable income, which is similar to earnings before interest, taxes, depreciation, and amortization. The limitation does not apply to interest expense that is properly allocable to a trade or business classified as a regulated public utility. This was further modified by a temporary provision of the CARES Act resulting in an increase of the adjusted taxable income limitation from 30% to 50% for tax years that begin in 2019 or 2020. The IRS issued final regulations which are effective for Entergy beginning with the 2021 tax year. The regulations provide that if 90% of a tax group’s consolidated assets consist of regulated utility property, the entire consolidated tax group will be treated as a regulated public utility and all of the consolidated group’s interest expense will be currently tax deductible. Entergy expects that this provision will continue to apply to Entergy’s business operations making the application of this limitation to Entergy less likely. The provision has not resulted in Entergy having to report any significant business interest expense limitations on its tax returns. With respect to the federal corporate income tax rate change from 35% to 21% in 2017, Entergy and the Registrant Subsidiaries recorded a regulatory liability associated with the decrease in the net accumulated deferred income tax liability, which is often referred to as “excess ADIT,” a significant portion of which has been paid to customers in 2019, 2020 and 2021 in the form of lower rates. Entergy’s December 31, 2021 and December 31, 2020 balance sheets reflect a regulatory liability of $1.3 billion and $1.6 billion, respectively, as a result of the re-measurement of deferred tax assets and liabilities from the income tax rate change, amortization of excess ADIT, and payments to customers during 2019, 2020 and 2021. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of a) the reduction of the net deferred tax liability resulting in excess ADIT, and b) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Ent

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings	12 Months Ended
	Dec. 31, 2021
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy Arkansas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy Louisiana [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy Mississippi [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy New Orleans [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy Texas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.
System Energy [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2021 was 1.60% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329 Entergy Corporation’s credit facility requires 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 Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of December 31, 2021, Entergy Corporation had $1.201 billion of commercial paper outstanding. The weighted-average interest rate for the year ended December 31, 2021 was 0.28%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. 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 entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of 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. The current FERC-authorized short-term borrowing limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through October 2023. 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 and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 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 2022. The commitment fee is currently 0.20% of the undrawn commitment amount. As of December 31, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the year ended December 31, 2021 was 1.67% on the drawn portion of the facility. See Note 14 to the financial statements for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

Long - Term Debt (Notes)

Long - Term Debt (Notes)	12 Months Ended
	Dec. 31, 2021
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Entergy Arkansas [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Entergy Louisiana [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Entergy Mississippi [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Entergy New Orleans [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Entergy Texas [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
System Energy [Member]
Long - Term Debt	LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720 Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 2023. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through December 2023. Entergy Arkansas has also obtained first mortgage bond/secured financing authorization from the APSC that extends through December 2022. Long-term debt for the Registrant Subsidiaries as of December 31, 2021 and 2020 consisted of: 2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632 2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294 2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432 2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634 2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193 2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540 (a) Consists of pollution control revenue bonds and environmental revenue bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt. (c) The bonds are secured by a series of collateral mortgage bonds. The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $— Entergy Louisiana Debt Issuance In December 2021, Entergy Louisiana entered into a term loan credit agreement providing a $1.2 billion unsecured term loan due June 2023. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable margin. Entergy Louisiana received the funds in January 2022 and used the proceeds for general corporate purposes, including storm restoration costs related to Hurricane Ida. Securitization Bonds Entergy Arkansas Securitization Bonds In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds, with a coupon of 2.30%. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in the amount of $7.3 million in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. Entergy Louisiana Securitization Bonds – Little Gypsy In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds had an interest rate of 2.04%. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in the amount of $11 million in 2021, after which the bonds were fully repaid. Entergy New Orleans Securitization Bonds - Hurricane Isaac In May 2015 the City Council issued a financing order authorizing the issuance of securitization bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs of $31.8 million, including carrying costs, the costs of funding and replenishing the storm recovery reserve in the amount of $63.9 million, and approximately $3 million of up-front financing costs associated with the securitization. In July 2015, Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly owned and consolidated by Entergy New Orleans, issued $98.7 million of storm cost recovery bonds. The bonds have a coupon of 2.67%. Although the principal amount is not due until June 2027, Entergy New Orleans Storm Recovery Funding expects to make principal payments on the bonds over the next three years in the amounts of $12.3 million for 2022, $12.5 million for 2023, and $6.2 million for 2024, after which the bonds will be fully repaid. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. Entergy Texas Securitization Bonds - Hurricane Rita In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds). Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in the amount of $17.5 million in 2021, after which the bonds were fully repaid. Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds). Although the principal amount is not due until November 2023, Entergy Texas Restoration Funding expects to make principal payments on the bonds in the amount of $54.3 million for 2022, after which the bonds will be fully repaid. With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections. Grand Gulf Sale-Leaseback Transactions In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases expired in July 2015. System Energy renewed the leases for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. As such, it has recognized debt for the lease obligation and retained the portion of the plant subject to the sale-leaseback on its balance sheet. For financial reporting purposes, System Energy has recognized interest expense on the debt balance and depreciation on the applicable plant balance. The lease payments are recognized as principal and interest payments on the debt balance. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory liability of $55.6 million as of December 31, 2021 and 2020. As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321

Preferred Equity (Notes)

Preferred Equity (Notes)	12 Months Ended
	Dec. 31, 2021
Preferred Equity	PREFERRED EQUITY AND NONCONTROLLING INTEREST (Entergy Corporation, Entergy Arkansas, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2021, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interest for Entergy Corporation subsidiaries as of December 31, 2021 and 2020 are presented below. Shares/Units Shares/Units 2021 2020 2021 2020 2021 2020 Entergy Corporation (Dollars in Thousands) Utility: Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (d) 150,000 — — — — — Entergy Arkansas Noncontrolling Interest — — — — 33,110 — Total Utility Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 1,750,000 1,600,000 1,600,000 1,600,000 263,271 230,161 Entergy Wholesale Commodities: Preferred Stock without sinking fund: Entergy Finance Holding, Inc. 8.75% (e) 250,000 250,000 250,000 250,000 24,249 24,249 Total Subsidiaries’ Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 2,000,000 1,850,000 1,850,000 1,850,000 $287,520 $254,410 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) Currently, all shares are held by Entergy Corporation. (e) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2021 and 2020 are presented below. Shares Call Price per 2021 2020 2021 2020 2021 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 — 3,750 — $25.50 Total without sinking fund 1,550,000 1,400,000 $38,750 $35,000 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2021 and 2020 is presented below. 2021 2020 (Dollars in Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $33,110 $— Total Noncontrolling Interest $33,110 $— (a) In December 2021, AR Searcy Partnership, LLC, a tax equity partnership between Entergy Arkansas and a tax equity investor, acquired the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is shown as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company (a Utility subsidiary) and Entergy Finance Holding (an Entergy Wholesale Commodities subsidiary), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income.
Entergy Texas [Member]
Preferred Equity	PREFERRED EQUITY AND NONCONTROLLING INTEREST (Entergy Corporation, Entergy Arkansas, and Entergy Texas) In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of December 31, 2021, no preferred stock has been issued. The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interest for Entergy Corporation subsidiaries as of December 31, 2021 and 2020 are presented below. Shares/Units Shares/Units 2021 2020 2021 2020 2021 2020 Entergy Corporation (Dollars in Thousands) Utility: Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (d) 150,000 — — — — — Entergy Arkansas Noncontrolling Interest — — — — 33,110 — Total Utility Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 1,750,000 1,600,000 1,600,000 1,600,000 263,271 230,161 Entergy Wholesale Commodities: Preferred Stock without sinking fund: Entergy Finance Holding, Inc. 8.75% (e) 250,000 250,000 250,000 250,000 24,249 24,249 Total Subsidiaries’ Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 2,000,000 1,850,000 1,850,000 1,850,000 $287,520 $254,410 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) Currently, all shares are held by Entergy Corporation. (e) In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series Preferred Stock, all of which are outstanding as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option, at the fixed redemption price of $100 per share. Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs. The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2021 and 2020 are presented below. Shares Call Price per 2021 2020 2021 2020 2021 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 — 3,750 — $25.50 Total without sinking fund 1,550,000 1,400,000 $38,750 $35,000 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026. Dividends and distributions paid on all of Entergy Corporation’s subsidiaries’ preferred stock and membership interests series may be eligible for the dividends received deduction. The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2021 and 2020 is presented below. 2021 2020 (Dollars in Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $33,110 $— Total Noncontrolling Interest $33,110 $— (a) In December 2021, AR Searcy Partnership, LLC, a tax equity partnership between Entergy Arkansas and a tax equity investor, acquired the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is shown as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Presentation of Preferred Stock without Sinking Fund Accounting standards regarding noncontrolling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity. The outstanding preferred securities of Entergy Utility Holding Company (a Utility subsidiary) and Entergy Finance Holding (an Entergy Wholesale Commodities subsidiary), whose preferred holders have protective rights, are presented between liabilities and equity on Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income.

Common Equity (Notes)

Common Equity (Notes)	12 Months Ended
	Dec. 31, 2021
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy Arkansas [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy Louisiana [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy Mississippi [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy New Orleans [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy Texas [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
System Energy [Member]
Common Equity	COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400 Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), the three equity plans of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation common stock. In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31, 2021, $350 million of authority remains under the $500 million share repurchase program. Dividends declared per common share were $3.86 in 2021, $3.74 in 2020, and $3.66 in 2019. Equity Distribution Program In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. During the year ended December 31, 2021, Entergy Corporation issued 1,930,330 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $200.8 million, which includes the gross sales price of $204.2 million received by Entergy Corporation less $1.4 million of general issuance costs and $2.0 million of aggregate compensation to the agents with respect to such sales. In June, August, and October 2021, Entergy entered into forward sale agreements for 416,853 shares, 1,692,555 shares, and 250,743 shares of common stock, respectively. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreements occur. The forward sale agreements require Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially approximately $106.87, $111.16, and $100.35 per share, respectively) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. 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 agreements. In connection with the forward sale agreements, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares, 1,692,555 shares, and 250,743 shares, respectively, of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million, $190.1 million, and $25.4 million, respectively. In connection with the sales of these shares, Entergy paid to the agents fees of $0.5 million, $1.9 million, and $0.3 million, respectively, which have not been deducted from the gross sales prices. Entergy did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. At December 31, 2021, 1,158,917 shares under the forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive. Equity Forward Sale Agreements In June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. The equity forwards required Entergy to, at its election prior to June 7, 2019, either (i) physically settle the transactions by issuing the total of 15.3 million shares of its common stock to the investment banks in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $74.45 per share) or (ii) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price was subject to adjustment on a daily basis based on a floating interest rate factor and decreased by other fixed amounts specified in the agreements. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of $500 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $728 thousand of common stock issuance costs with the settlement. In May 2019, Entergy physically settled its remaining obligations under the forward sale agreements by delivering 8,448,171 shares of common stock in exchange for cash proceeds of $608 million. The forward sale price used to determine the cash proceeds received by Entergy was calculated based on the initial forward sale price of $74.45 per share as adjusted in accordance with the forward sale agreements. Entergy incurred approximately $7 thousand of common stock issuance costs with the settlement. Entergy used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy’s revolving credit facility, and other debt. Retained Earnings and Dividends Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Entergy Corporation received dividend payments and distributions from subsidiaries totaling $136 million in 2021, $113 million in 2020, and $124 million in 2019. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
Entergy Arkansas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
Entergy Louisiana [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
Entergy Mississippi [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
Entergy New Orleans [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
Entergy Texas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability
System Energy [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Vidalia Purchased Power Agreement Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $128.5 million in 2021, $132.7 million in 2020, and $135.5 million in 2019. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $137 million in 2022, and a total of $1.23 billion for the years 2023 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause. In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In October 2011 the LPSC approved a settlement under which Entergy Louisiana agreed to provide credits to customers by crediting billings an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to reflect this obligation. The settlement agreement allowed for an adjustment to the credits if, among other things, there was a change in the applicable federal or state income tax rate. As a result of the enactment of the Tax Cuts and Jobs Act, in December 2017, and the lowering of the federal corporate income tax rate from 35% to 21%, the Vidalia purchased power regulatory liability was reduced by $30.5 million, with a corresponding increase to Other regulatory credits on the income statement. The effects of the Tax Cuts and Jobs Act are discussed further in Note 3 to the financial statements. Pursuant to legislation enacted in 2021 and approved by Louisiana citizens by amendment to the state constitution, beginning January 1, 2022, federal income taxes paid will no longer be deductible for state income tax purposes, and the top Louisiana corporate income tax rate will be reduced from 8% to 7.5%. As a result of this change in Louisiana tax law, deferred taxes must be adjusted to reflect the applicable federal and state rates which has a corresponding effect on the Vidalia regulatory liability. Such effect is not expected to be significant. ANO Damage, Outage, and NRC Reviews In March 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building. The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was approximately $95 million. Entergy Arkansas pursued its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action. Entergy Arkansas collected $50 million in 2014 from Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants. Entergy Arkansas also collected a total of $21 million in 2018 as a result of stator-related settlements. In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC authorized Entergy Arkansas to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information regarding various claims associated with the ANO stator incident is available. In March 2015, after several NRC inspections and regulatory conferences, arising from the stator incident, the NRC placed ANO into the “multiple/repetitive degraded cornerstone column,” or Column 4, of the NRC’s Reactor Oversight Process Action Matrix. Entergy Arkansas incurred incremental costs of approximately $53 million in 2015 to prepare for the NRC inspections that began in early 2016 in order to address the issues required to move ANO back to “licensee response” or Column 1 of the NRC’s Reactor Oversight Process Action Matrix. Excluding remediation and response costs that resulted from the additional NRC inspection activities, Entergy Arkansas incurred approximately $44 million in 2016 and $7 million in 2017 in support of NRC inspection activities and to implement Entergy Arkansas’s performance improvement initiatives developed in 2015. In June 2018 the NRC moved ANO 1 and ANO 2 into the “licensee response column,” or Column 1, of the NRC’s Reactor Oversight Process Action Matrix. In July 2017, Entergy Arkansas filed for a change in rates pursuant to its formula rate plan rider. In that proceeding, the APSC approved a settlement agreement agreed upon by the parties, including a provision that requires Entergy Arkansas to initiate a regulatory proceeding for the purpose of recovering funds currently withheld from rates and related to the stator incident, including the $65.9 million of deferred fuel and purchased energy costs and costs related to the incremental oversight previously noted, subject to certain timelines and conditions set forth in the settlement agreement. In October 2021 the APSC approved Entergy Arkansas’s second request to extend the deadline for initiating a regulatory proceeding for the purpose of recovering funds related to the stator incident for twelve additional months, or until December 1, 2022. Spent Nuclear Fuel Litigation Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries have been charged fees for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Following the defunding of the Yucca Mountain spent fuel repository program, the National Association of Regulatory Utility Commissioners and others sued the government seeking cessation of collection of the one mill per net kWh generated and sold after April 7, 1983 fee. In November 2013 the D.C. Circuit Court of Appeals ordered the DOE to submit a proposal to Congress to reset the fee to zero until the DOE complies with the Nuclear Waste Policy Act or Congress enacts an alternative waste disposal plan. In January 2014 the DOE submitted the proposal to Congress under protest, and also filed a petition for rehearing with the D.C. Circuit. The petition for rehearing was denied. The zero spent fuel fee went into effect prospectively in May 2014. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. As a result of the DOE’s failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy’s nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. Beginning in November 2003 these subsidiaries have pursued litigation to recover the damages caused by the DOE’s delay in performance. Following are details of final judgments recorded by Entergy in 2019, 2020, and 2021 related to Entergy’s nuclear owner licensee subsidiaries’ litigation with the DOE. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously recorded as plant. In December 2019 the DOE submitted an offer of judgment to resolve claims in the third round ANO damages case. The $80 million offer was accepted by Entergy Arkansas, and the U.S. Court of Federal Claims issued a judgment in that amount in favor of Entergy Arkansas and against the DOE. Entergy Arkansas received payment from the U.S. Treasury in January 2020. The effects in 2019 of recording the judgment were reductions to plant, nuclear fuel expense, other operation and maintenance expense, depreciation expense, and taxes other than income taxes. The ANO damages awarded included $55 million in costs previously recorded as plant, $12 million related to costs previously recorded as nuclear fuel expense, $12 million related to costs previously recorded as other operation and maintenance expense, and $1 million related to costs previously recorded as taxes other than income taxes. Of the $55 million, Entergy Arkansas, recorded $5 million as a reduction to previously-recorded depreciation expense. In December 2019 the Entergy FitzPatrick Properties (formerly Entergy Nuclear FitzPatrick) and the DOE entered into a settlement agreement and the U.S. Court of Federal Claims issued a judgment in the amount of $7 million in favor of Entergy FitzPatrick Properties against the DOE in the second round FitzPatrick damages case. Entergy received payment from the U.S. Treasury in January 2020. Substantially all of the FitzPatrick damages awarded relate to costs previously expensed as asset write-offs, impairments, and related charges, and in December 2019 Entergy recorded $7 million as a reduction to asset write-offs, impairments, and related charges. In April 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $33 million in favor of Entergy Louisiana against the DOE in the second round Waterford 3 damages case. Entergy Louisiana received payment from the U.S. Treasury in June 2020. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The Waterford 3 damages awarded included $20 million related to costs previously recorded as nuclear fuel expense, $8 million related to costs previously recorded as other operation and maintenance expenses, and $5 million in costs previously recorded as plant. In October 2020 the U.S. Court of Federal Claims issued a final judgment in the amount of $40.5 million in favor of System Energy and against the DOE in the third round Grand Gulf damages case. System Energy received payment from the U.S. Treasury in December 2020. The effects of recording the judgment w ere reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The amounts of Grand Gulf damages awarded related to System Energy’s 90% ownership of Grand Gulf included $5 million related to costs previously recorded as plant, $21 million related to costs previously recorded as nuclear fuel expense, and $10 million related to costs previously recorded as other operation and maintenance expense. In January 2021 the U.S. Court of Federal Clams issued a final judgment in the amount of $23 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $16 million related to costs previously recorded as plant, and $7 million related to costs previously recorded as other operation and maintenance expenses. Of the $16 million previously capitalized, Entergy recorded $9 million as a reduction to previously-recorded depreciation expense. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $37.6 million in favor of Holtec Pilgrim, LLC against the DOE in the third round Pilgrim damages case. Holtec Pilgrim, LLC received the payment from the U.S. Treasury in September 2021. The judgment proceeds were subsequently transferred to Entergy pursuant to the terms of the Pilgrim sale. The receipt of the proceeds was recorded as a deferred credit because Entergy has an indemnity obligation to Holtec related to pre-sale DOE litigation involving Pilgrim that remains outstanding. In August 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $21 million in favor of Entergy Louisiana against the DOE in the third round River Bend damages case. Entergy Louisiana received the payment from the U.S. Treasury in September 2021. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $9 million in costs previously capitalized, $8 million related to costs previously recorded as nuclear fuel expense, and $4 million related to costs previously recorded as other operation and maintenance expense. In October 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $83 million in favor of Entergy Nuclear Indian Point 2, LLC and Entergy Nuclear Indian Point 3, LLC against the DOE in the Indian Point Unit 2 third round and Unit 3 second round combined damages case. Entergy received payment from the U. S. Treasury in January 2022. The effect of recording the judgment was a reduction to asset write-offs, impairments, and related charges. The damages awarded included $32 million related to costs previously recorded as plant, $47 million related to costs previously recorded as other operation and maintenance expenses, and $4 million related to costs previously recorded as taxes other than income taxes. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards. Nuclear Insurance Third Party Liability Insurance The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage: 1. The primary level is private i nsurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $450 million for each operating reactor. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies. 2. Secondary Financial Protection: Curr ently, 95 nuclear reactors participate in the Secondary Financial Protection program, which provides approximately $13 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers. Within the Secondary Financial Protection program, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maxi mum of approximately $137.6 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $826 million following the recent sale of the Indian Point Energy Center in May 2021). This retrospective premium is assessable at approximately $21 million per year per incident per nuclear power reactor. 3. Total insurance coverage available is approximately $13.5 billion, among the primary ANI coverage and the Secondary Financial Protection program, to respond to a nuclear power plant accident that causes third-party damages (e.g. off-site property and environmental damage, off-site bodily injury and on-site third-party bodily injury (i.e. contractors)). These coverages also respond to an accident caused by terrorism. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. The shutdown Big Rock Point facility maintains its site-specific statutory nuclear liability insurance requirement limit of $44.4 million, as designated by the NRC. Entergy Arkansas and Entergy Louisiana each have two licensed reactors. System Energy has one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (Cooperative Energy) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of one remaining nuclear power reactor at Palisades and the ownership of the shutdown Big Rock Point facility. The Indian Point Energy Center was sold to Holtec in late May 2021, following the final shutdown of Indian Point Unit 2 and Indian Point Unit 3 in April 2020 and 2021, respectively. Palisades is scheduled for shutdown in May 2022, with sale of Palisades and Big Rock to follow soon thereafter. The Entergy Wholesale Commodities segment previously included three nuclear power reactors that were sold (FitzPatrick sold in March 2017, Vermont Yankee sold in January 2019, and Pilgrim sold in August 2019) in addition to the recently sold Indian Point Energy Center. Property Insurance Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides property damage coverage, including decontamination and reactor stabilization, to the members’ nuclear generating plants. The property damage insurance limits procured by Entergy for its Utility plants and Entergy Wholesale Commodity plants are in compliance with the financial protection requirements of the NRC. The Utility plants’ (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3) property damage insurance limits are $1.5 billion per occurrence at each plant with an additional $100 million per nuclear property occurrence that is shared among the plants. The nuclear property deductible is $10 million per site at the Utility plants, except for earth movement, flood, and windstorm. Property damage from earth movement is excluded from the first $500 million in coverage for all Utility plants. Property damage from flood is excluded from the first $500 million in coverage at ANO 1 and 2 and Grand Gulf. Property damage from flood for Waterford 3 and River Bend includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from wind for all of the Utility nuclear plants includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a total maximum deductible of $50 million. The Entergy Wholesale Commodities’ plants (Palisades and Big Rock Point) have property damage insurance limits as follows: Big Rock Point - $50 million per occurrence and Palisades - $1.115 billion per occurrence. For losses that are considered non-nuclear in nature, the property damage insurance limit at Palisades is $500 million. The nuclear property deductible is $10 million at Palisades and $5 million at Big Rock Point, except for earth movement, flood, and windstorm. Property damage from earth movement, flood, and windstorm at Palisades includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $50 million. Property damage from earth movement, flood, and windstorm at Big Rock Point includes a deductible of $10 million plus an additional 10% of the amount of the loss in excess of $10 million, up to a maximum deductible of $14 million. The valuation basis of the insured property at Palisades has been changed from replacement cost to actual cash value, given the site’s age, anti cipated ownership horizon and/or shutdown status. In addition, Waterford 3 and Grand Gulf are also covered under NEIL’s Accidental Outage Coverage program. Accidental outage coverage provides indemnification for the actual cost incurred in the event of an unplanned outage resulting from property damage covered under the NEIL Primary Property Insurance policy, subject to a deductible period. The indemnification for the actual cost incurred is based on market power prices at the time of the loss. After the deductible period has passed, weekly indemnities for an unplanned outage, covered under NEIL’s Accidental Outage Coverage program, would be paid according to the amounts listed below: • 100% of the weekly indemnity for each week for the first payment period of 52 weeks; then • 80% of the weekly indemnity for each week for the second payment period of 52 weeks; and thereafter • 80% of the weekly indemnity for an additional 58 weeks for the third and final payment period. Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A * *Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors. In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate not exceedi ng $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. Under current law, the Terrorism Risk Insurance Act extends through 2027. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) Numerous lawsuits have been filed in state courts against primarily Entergy Texas and Entergy Louisiana by individuals alleging exposure to asbestos while working at Entergy facilities between 1955 and 1980. Entergy is being sued as a premises owner. Many other defendants are named in these lawsuits as well. Currently, there are approximately 200 lawsuits involving approximately 325 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2021 under the agreement were approximately $16.4 million for Entergy Arkansas, $6.5 million for Entergy Louisiana, $14.6 million for Entergy Mississippi, and $7.9 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
Entergy Arkansas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
Entergy Louisiana [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
Entergy Mississippi [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
Entergy New Orleans [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
Entergy Texas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.
System Energy [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9 As of December 31, 2021 and 2020, the regulatory asset for removal costs for the Utility operating companies includes amounts related to storm restoration costs. See Note 2 to the financial statements for further discussion of storm restoration costs and requested recovery. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021. Nuclear Plant Decommissioning Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of the timing of plant decommissioning, regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. Entergy did not update decommissioning cost estimates in 2021 or 2020. NRC Filings Regarding Trust Funding Levels Plant owners are required to provide the NRC with a biennial report (annually for units that have shut down or will shut down within five years), based on values as of December 31, addressing the owners’ ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, plant owners may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As nuclear plants individually approach and begin decommissioning, filings will be submitted to the NRC for planned shutdown activities. These filings with the NRC also determine whether financial assurance may be required in addition to the nuclear decommissioning trust fund. Coal Combustion Residuals In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contained two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of Resource Conservation and Recovery Act (RCRA) Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially reused in certain processes would remain excluded from hazardous waste regulation. In April 2015 the EPA published the final CCR rule with the material being regulated under the second scenario presented above - as non-hazardous wastes regulated under RCRA Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed for CCR that cannot be transferred for beneficial reuse. In December 2016 the Water Infrastructure Improvements for the Nation Act (WIIN Act) was signed into law, which authorizes states to regulate coal ash rather than leaving primary enforcement to citizen suit actions. States may submit to the EPA proposals for permit programs.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
Entergy Arkansas [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
Entergy Louisiana [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
Entergy Mississippi [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
Entergy New Orleans [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
Entergy Texas [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.
System Energy [Member]
Lessor, Sales-type Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) As of December 31, 2021 and 2020, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases under the accounting standards. Leases have remaining terms of one year to 59 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884 Of the lease costs disclosed above, Entergy had $2.8 million and $759 thousand in short-term leases costs for the years ended December 31, 2021 and 2020, respectively. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 Of the lease costs disclosed above, Entergy Arkansas had $826 thousand, Entergy Louisiana had $934 thousand, Entergy Mississippi had $703 thousand, Entergy New Orleans had $77 thousand, and Entergy Texas had $261 thousand in short-term lease costs for the year ended December 31, 2021. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196 Of the lease costs disclosed above, Entergy Arkansas had $43 thousand and Entergy Louisiana had $719 thousand in short-term lease costs for the year ended December 31, 2020. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at December 31, 2021 and 2020 are $ 212 million 230 million 67 million 60 million Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 % Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309 Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

Retirement, Other Postretiremen

Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Notes)	12 Months Ended
	Dec. 31, 2021
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Qualified Pension Plans Entergy has eight defined benefit qualified pension plans. The Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees, the Entergy Corporation Retirement Plan III, and the Entergy Corporation Retirement Plan IV for Bargaining Employees are non-contributory final average pay plans that provide pension benefits based on employees’ credited service and compensation during employment. Non-bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 do not participate in a final average pay plan, but instead participate in the Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan). Effective January 1, 2021, the Non-Bargaining Cash Balance Plan was closed to non-bargaining employees whose most recent date of hire is after December 31, 2020, who instead may be eligible to participate in, and receive a discretionary employer contribution under, the Savings Plan of Entergy Corporation and Subsidiaries VIII, an Entergy-sponsored tax-qualified defined contribution plan that includes a 401(k) feature. Certain bargaining employees whose most recent date of hire is after June 30, 2014, or such later date provided for in their applicable collective bargaining agreements, participate in the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). Effective January 1, 2021, the Bargaining Cash Balance Plan was amended to close participation in the plan to those bargaining employees whose most recent hire date is after December 31, 2020 or such later date provided for in their applicable collective bargaining agreements. The Registrant Subsidiaries participate in these four plans: Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Cash Balance Plan, and Bargaining Cash Balance Plan. Effective January 1, 2022, the Non-Bargaining Cash Balance Plan was merged with and into Non-Bargaining Plan I. The assets of the six final average pay defined benefit qualified pension plans are held in a master trust established by Entergy, and the assets of the two cash balance pension plans are held in a second master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trusts on a pro rata basis. Effective January 1, 2022, the assets of the remaining cash balance pension plan held in a second master trust were merged with and into a master trust that holds the assets of the six final average pay defined benefit qualified pension plans. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss (i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960 The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656 Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010 Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $— (a) Including settlement lump sum benefit payments of ($48.4) million at Entergy Arkansas, ($18.6) million at Entergy Louisiana, ($7.7) million at Entergy Mississippi, ($9.8) million at Entergy Texas, and ($236) thousand at System Energy. The qualified pension plans incurred actuarial gains during 2021 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets exceeding the expected return on assets for 2021. The qualified pension plans incurred actuarial losses during 2020 primarily due to a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020. Accumulated Pension Benefit Obligation The accumulated benefit obligation for Entergy’s qualified pension plans was $7.8 billion and $8.4 billion at December 31, 2021 and 2020, respectively. The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296 Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), will be eligible to participate in a new Entergy-sponsored retiree health plan, and will no longer be eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants will be eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change are reflected in the December 31, 2020 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefit costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172) Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452) Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216) Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $— The other postretirement plans incurred actuarial losses during 2021 primarily due to a reduction in the projected Employer Group Waiver Plan (EGWP) revenue and updated census data. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2021 and a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred actuarial losses during 2020 primarily due to a reduction in the projected EGWP revenue and a fall in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. These losses were partially offset by gains resulting from the actual return on assets exceeding the expected return on assets for 2020, an update to the latest mortality projection scale MP-2020, and favorable claims experience. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. Entergy recognized net periodic pension cost related to these plans of $28.6 million in 2021, $18.1 million in 2020, and $22.6 million in 2019. In 2021 and 2019 Entergy recognized $10.9 million and $7.4 million, respectively in settlement charges related to the payment of lump sum benefits out of the plan that is included in the non-qualified pension plan cost above. In 2020 there were no settlement charges related to the payment of lump sum benefits out of the plan. The projected benefit obligation was $181.6 million as of December 31, 2021 of which $26.3 million was a current liability and $155.3 million was a non-current liability. The projected benefit obligation was $182.4 million as of December 31, 2020 of which $22.9 million was a current liability and $159.5 million was a non-current liability. The accumulated benefit obligation was $165.5 million and $161.3 million as of December 31, 2021 and 2020, respectively. The unamortized prior service cost and net loss are recognized in regulatory assets ($74.9 million at December 31, 2021 and $77.3 millio

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement, Noncash Expense [Abstract]
Stock-Based Compensation	STOCK-BASED COMPENSATION (Entergy Corporation)Entergy grants stock options, restricted stock, performance units, and restricted stock units to key employees of the Entergy subsidiaries under its equity plans which are shareholder-approved stock-based compensation plans. Effective May 3, 2019, Entergy’s shareholders approved the 2019 Omnibus Incentive Plan (2019 Plan). The maximum number of common shares that can be issued from the 2019 Plan for stock-based awards is 7,300,000 all of which are available for incentive stock option grants. The 2019 Plan applies to awards granted on or after May 3, 2019 and awards expire ten years from the date of grant. As of December 31, 2021, there were 4,711,095 authorized shares remaining for stock-based awards. Stock Options Stock options are granted at exercise prices that equal the closing market price of Entergy Corporation common stock on the date of grant. Generally, stock options granted will become exercisable in equal amounts on each of the first three anniversaries of the date of grant. Unless they are forfeited previously under the terms of the grant, options expire 10 years after the date of the grant if they are not exercised. The following table includes financial information for stock options for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $4.2 $3.9 $3.8 Tax benefit recognized in Entergy’s consolidated net income $1.1 $1.0 $1.0 Compensation cost capitalized as part of fixed assets and inventory $1.5 $1.5 $1.4 Entergy determines the fair value of the stock option grants by considering factors such as lack of marketability, stock retention requirements, and regulatory restrictions on exercisability in accordance with accounting standards. The stock option weighted-average assumptions used in determining the fair values are as follows: 2021 2020 2019 Stock price volatility 23.93% 17.16% 17.23% Expected term in years 6.93 7.04 7.32 Risk-free interest rate 0.74% 1.49% 2.50% Dividend yield 4.00% 4.00% 4.50% Dividend payment per share $3.86 $3.74 $3.66 Stock price volatility is calculated based upon the daily public stock price volatility of Entergy Corporation common stock over a period equal to the expected term of the award. The expected term of the options is based upon historical option exercises and the weighted average life of options when exercised and the estimated weighted average life of all vested but unexercised options. In 2008, Entergy implemented stock ownership guidelines for its senior executive officers. These guidelines require an executive officer to own shares of Entergy Corporation common stock equal to a specified multiple of his or her salary. Until an executive officer achieves this ownership position the executive officer is required to retain 75% of the net-of-tax net profit upon exercise of the option to be held in Entergy Corporation common stock. The reduction in fair value of the stock options due to this restriction is based upon an estimate of the call option value of the reinvested gain discounted to present value over the applicable reinvestment period. A summary of stock option activity for the year ended December 31, 2021 and changes during the year are presented below: Number of Options Weighted- Aggregate Intrinsic Value Weighted- Options outstanding as of January 1, 2021 2,399,379 $89.63 Options granted 508,704 $95.87 Options exercised (72,138) $80.54 Options forfeited/expired (16,301) $117.89 Options outstanding as of December 31, 2021 2,819,644 $90.82 $71,110,949 6.34 years Options exercisable as of December 31, 2021 1,788,702 $81.91 $58,164,228 5.16 years Weighted-average grant-date fair value of options granted during 2021 $12.27 The weighted-average grant-date fair value of options granted during the year was $11.45 for 2020 and $8.32 for 2019. The total intrinsic value of stock options exercised was $2 million during 2021, $26 million during 2020, and $29 million during 2019. The intrinsic value, which has no effect on net income, of the outstanding stock options exercised is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of December 31, 2021. The aggregate intrinsic value of the stock options outstanding as of December 31, 2021 was $71.1 million. Stock options outstanding as of December 31, 2021 includes 501,316 out of the money options with an intrinsic value of zero. Entergy recognizes compensation cost over the vesting period of the options based on their grant-date fair value. The total fair value of options that vested was approximately $5 million during 2021, $5 million during 2020, and $5 million during 2019. Cash received from option exercises was $6 million for the year ended December 31, 2021. The tax benefits realized from options exercised was $0.5 million for the year ended December 31, 2021. The following table summarizes information about stock options outstanding as of December 31, 2021: Options Outstanding Options Exercisable Range of Exercise Price As of December 31, 2021 Weighted-Average Remaining Contractual Life-Yrs. Weighted Average Exercise Price Number Exercisable as of December 31, 2021 Weighted Average Exercise Price $51 - $64.99 240,200 1.72 $63.69 240,200 $63.69 $65 - $78.99 915,839 5.19 $73.80 915,839 $73.80 $79 - $91.99 653,585 6.21 $89.35 465,577 $89.41 $92 - $131.72 1,010,020 8.58 $113.66 167,086 $131.72 $51 - $131.72 2,819,644 6.34 $90.82 1,788,702 $81.91 Stock-based compensation cost related to non-vested stock options outstanding as of December 31, 2021 not yet recognized is approximately $7 million and is expected to be recognized over a weighted-average period of 1.72 years. Restricted Stock Awards Entergy grants restricted stock awards earned under its stock benefit plans in the form of stock units. One-third of the restricted stock awards will vest upon each anniversary of the grant date and are expensed ratably over the three-year vesting period. Shares of restricted stock have the same dividend and voting rights as other common stock and are considered issued and outstanding shares of Entergy upon vesting. In January 2021 the Board approved and Entergy granted 392,383 restricted stock awards under the 2019 Plan. The restricted stock awards were made effective on January 28, 2021 and were valued at $95.87 per share, which was the closing price of Entergy Corporation’s common stock on that date. The following table includes information about the restricted stock awards outstanding as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 648,498 $107.89 Granted 419,095 $96.45 Vested (323,698) $99.28 Forfeited (58,540) $108.57 Outstanding shares at December 31, 2021 685,355 $104.91 The following table includes financial information for restricted stock for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $24.7 $23.1 $20.2 Tax benefit recognized in Entergy’s consolidated net income $6.3 $5.9 $5.1 Compensation cost capitalized as part of fixed assets and inventory $9.3 $8.5 $7.1 The total fair value of the restricted stock awards granted was $40 million, $44 million, and $34 million for the years ended December 31, 2021, 2020, and 2019, respectively. The total fair value of the restricted stock awards vested was $32 million, $27 million, and $25 million for the years ended December 31, 2021, 2020, and 2019, respectively. Long-Term Performance Unit Program Entergy grants long-term incentive awards earned under its stock benefit plans in the form of performance units, which represents the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. The Long-Term Performance Unit Program specifies a minimum, target, and maximum achievement level, the achievement of which will determine the number of performance units that may be earned. Entergy measures performance by assessing Entergy’s total shareholder return relative to the total shareholder return of the companies in the Philadelphia Utility Index. To emphasize the importance of strong cash generation for the long-term health of its business, Entergy Corporation replaced the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 performance period. For the 2021-2023 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit metric. In January 2021 the Board approved and Entergy granted 203,983 performance units under the 2019 Plan. The performance units were granted on January 28, 2021, and eighty percent were valued at $110.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $95.87 per share, the closing price of Entergy Corporation’s common stock on that date. Performance units have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the 3-year vesting period, and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. The following table includes information about the long-term performance units outstanding at the target level as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 475,765 $110.82 Granted 303,092 $104.02 Vested (235,983) $82.42 Forfeited (21,038) $122.87 Outstanding shares at December 31, 2021 521,836 $119.23 The following table includes financial information for the long-term performance units for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $14.5 $12.6 $11.1 Tax benefit recognized in Entergy’s consolidated net income $3.7 $3.2 $2.8 Compensation cost capitalized as part of fixed assets and inventory $5.8 $4.9 $4.0 The total fair value of the long-term performance units granted was $32 million, $40 million, and $23 million for the years ended December 31, 2021, 2020, and 2019, respectively. In January 2021, Entergy issued 235,983 shares of Entergy Corporation common stock at a share price of $95.12 for awards earned and dividends accrued under the 2018-2020 Long-Term Performance Unit Program. In January 2020, Entergy issued 423,184 shares of Entergy Corporation common stock at a share price of $126.31 for awards earned and dividends accrued under the 2017-2019 Long-Term Performance Unit Program. In January 2019, Entergy issued 226,208 shares of Entergy Corporation common stock at a share price of $86.03 for awards earned and dividends accrued under the 2016-2018 Long-Term Performance Unit Program. Restricted Stock Unit Awards Entergy grants restricted stock unit awards earned under its stock benefit plans in the form of stock units that are subject to time-based restrictions. The restricted stock units may be settled in shares of Entergy Corporation common stock or the cash value of shares of Entergy Corporation common stock at the time of vesting. The costs of restricted stock unit awards are charged to income over the restricted period, which varies from grant to grant. The average vesting period for restricted stock unit awards granted is 35 months. As of December 31, 2021, there were 88,648 unvested restricted stock units that are expected to vest over an average period of 18 months. The following table includes information about the restricted stock unit awards outstanding as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 86,175 $92.92 Granted 39,478 $105.06 Vested (37,005) $90.89 Outstanding shares at December 31, 2021 88,648 $99.18 The following table includes financial information for restricted stock unit awards for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $1.9 $2.0 $2.2 Tax benefit recognized in Entergy’s consolidated net income $0.5 $0.5 $0.6 Compensation cost capitalized as part of fixed assets and inventory $0.7 $0.9 $0.9 The total fair value of the restricted stock unit awards granted was $4 million, $2 million, and $3 million for the years ended December 31, 2021, 2020, and 2019, respectively. The total fair value of the restricted stock unit awards vested was $3 million, $4 million, and $5.9 million for the years ended December 31, 2021, 2020, and 2019, respectively.

Business Segment Information (N

Business Segment Information (Notes)	12 Months Ended
	Dec. 31, 2021
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
Entergy Arkansas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
Entergy Louisiana [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
Entergy Mississippi [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
Entergy New Orleans [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
Entergy Texas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.
System Energy [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)Entergy’s reportable segments as of December 31, 2021 were Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. Results of operations for 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements for further discussion of the sale of the Indian Point Energy Center. Results of operations for 2020 include resolution of the 2014-2015 IRS audit, which resulted in a reduction in deferred income tax expense of $230 million that includes a $396 million reduction in deferred income tax expense at Utility related to the basis of assets contributed in the 2015 Entergy Louisiana and Entergy Gulf States Louisiana business combination, including the recognition of previously uncertain tax positions, and deferred income tax expense of $105 million at Entergy Wholesale Commodities and $61 million at Parent and Other resulting from the revaluation of net operating losses as a result of the release of the reserves. See Note 3 to the financial statements for further discussion of the IRS audit resolution. Results of operations for 2019 include: 1) a loss of $190 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019; 2) a $156 million reduction in income tax expense recognized by Entergy Wholesale Commodities as a result of an internal restructuring; and 3) impairment charges of $100 million ($79 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 3 to the financial statements for further discussion of the internal restructuring. See Note 14 to the financial statements for further discussion of the sale of the Pilgrim plant. Entergy Wholesale Commodities In January 2019, Entergy sold the Vermont Yankee plant, which it had previously shut down, to NorthStar. In August 2019, Entergy sold the Pilgrim plant, which it had previously shut down, to Holtec. In May 2021, Entergy sold Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. Entergy has also announced plans to shut down Palisades in May 2022 and has a purchase and sale agreement with Holtec expected to close after the plant is shut down . Management expects these transactions to result in the cessation of merchant power generation at all Entergy Wholesale Commodities nuclear power plants owned and operated by Entergy by 2022. Entergy will continue to have the obligation to decommission the Palisades plant pending its sale to Holtec. The decisions to shut down these plants and the related transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. The employee retention and severance expenses and other benefits-related costs and contracted economic development contributions are included in "Other operation and maintenance" in the consolidated income statements. Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37 In addition, Entergy Wholesale Commodities incurred $264 million in 2021, $19 million in 2020, and $290 million in 2019 of impairment, loss on sales, and other related charges associated with these strategic decisions and transactions. See Note 14 to the financial statements for further discussion of these impairment charges. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses of approximately $5 million in 2022 associated with these strategic transactions. Geographic Areas For the years ended December 31, 2021, 2020, and 2019, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2021 and 2020, Entergy had no long-lived assets located outside of the United States. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is 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.

Acquisitions, Dispositions, and

Acquisitions, Dispositions, and Impairment of Long-Lived Assets (Notes)	12 Months Ended
	Dec. 31, 2021
Acquisitions And Dispositions	ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Arkansas [Member]
Acquisitions And Dispositions	ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Louisiana [Member]
Acquisitions And Dispositions	ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Mississippi [Member]
Acquisitions And Dispositions	ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.

Risk Management And Fair Values

Risk Management And Fair Values (Notes)	12 Months Ended
	Dec. 31, 2021
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
Entergy Arkansas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
Entergy Louisiana [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
Entergy Mississippi [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
Entergy New Orleans [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
Entergy Texas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of
System Energy [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets. In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk. When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 99% for 2022, all of which is sold under normal purchase/normal sale contracts. Total planned generation for 2022 is 2.8 TWh. Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contained provisions that required an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements was an Entergy Corporation guarantee. If the Entergy Corporation credit rating fell below investment grade, Entergy would have had to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of December 31, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2021, $8 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2021 is 2.25 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of December 31, 2021 is 10 months for Entergy Mississippi and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2021 is 33,083,500 MMBtu for Entergy, including 16,420,000 MMBtu for Entergy Louisiana, 16,017,800 MMBtu for Entergy Mississippi, and 645,700 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. 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 Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2021 is 57,836 GWh for Entergy, including 12,561 GWh for Entergy Arkansas, 25,973 GWh for Entergy Louisiana, 6,429 GWh for Entergy Mississippi, 2,643 GWh for Entergy New Orleans, and 10,003 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 Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2021 and 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi and Entergy Texas as of December 31, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of December 31, 2021 letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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 and derivative power contracts used as cash flow hedges of power sales at merchant power plants. Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight report to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model, and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy and within Entergy Wholesale Commodities. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy and Entergy Wholesale Commodities. 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 Entergy Wholesale Commodities 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 Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of

Decommissioning Trust Funds

Decommissioning Trust Funds	12 Months Ended
	Dec. 31, 2021
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 14 to the financial statements, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. 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 year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $605 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $2,177 $65 $12 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $2 million as of December 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $2,125 million as of December 31, 2021 and $2,423 million as of December 31, 2020. As of December 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.74%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.55 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $770 $8 $187 $3 More than 12 months 99 4 2 — Total $869 $12 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 473 672 5 years - 10 years 655 852 10 years - 15 years 389 377 15 years - 20 years 130 144 20 years+ 530 576 Total $2,177 $2,617 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $1,465 million, $1,024 million, and $1,427 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $29 million, $47 million, and $25 million, respectively, and gross losses of $17 million, $4 million, and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of December 31, 2021 was $576 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $526.3 $11.4 $4.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $519.6 million as of December 31, 2021 and $420.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.44 years, and an average maturity of approximately 7.58 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $163.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $183.8 $2.9 $29.9 $0.3 More than 12 months 39.5 1.8 — — Total $223.3 $4.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 91.7 113.1 5 years - 10 years 217.4 189.8 10 years - 15 years 146.0 81.4 15 years - 20 years 35.7 28.5 20 years+ 35.5 35.1 Total $526.3 $447.9 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $57.6 million, $94.5 million, and $110.6 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $2.5 million, $8.8 million, and $2.9 million, respectively, and gross losses of $0.6 million, $0.2 million, and $0.1 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $794.2 $31.3 $3.3 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $766.3 million as of December 31, 2021 and $581.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.30%, an average duration of approximately 6.83 years, and an average maturity of approximately 12.29 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $249.4 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $206.9 $1.4 $36.4 $0.5 More than 12 months 42.9 1.9 0.8 — Total $249.8 $3.3 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 157.8 117.0 5 years - 10 years 173.0 159.4 10 years - 15 years 123.0 101.2 15 years - 20 years 80.2 66.9 20 years+ 260.2 187.7 Total $794.2 $632.2 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $303.4 million, $159.7 million, and $186 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $6.8 million, $8.1 million, and $4.8 million, respectively, and gross losses of $4.1 million, $0.7 million, and $0.3 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $524.5 $11.8 $2.9 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $515.6 million as of December 31, 2021 and $398.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.33%, an average duration of approximately 7.33 years, and an average maturity of approximately 10.15 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $155.1 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $276.6 $2.3 $28.9 $0.8 More than 12 months 11.3 0.6 — — Total $287.9 $2.9 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 156.8 134.7 5 years - 10 years 161.8 141.5 10 years - 15 years 58.6 31.5 15 years - 20 years 1.9 5.3 20 years+ 145.4 115.8 Total $524.5 $427.7 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $513.8 million, $252.2 million, and $338.1 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $9.3 million, $11.5 million, and $5.4 million, respectively, and gross losses of $4.0 million, $0.6 million, and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit losses Entergy implemented ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, effective January 1, 2020. In accordance with the new standard, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an individual security is determined to be uncollectible it is written off against this allowance. Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities. As of December 31, 2021 and 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the years ended December 31, 2021 and 2020. Other-than-temporary impairments and unrealized gains and losses
Entergy Arkansas [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 14 to the financial statements, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. 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 year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $605 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $2,177 $65 $12 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $2 million as of December 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $2,125 million as of December 31, 2021 and $2,423 million as of December 31, 2020. As of December 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.74%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.55 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $770 $8 $187 $3 More than 12 months 99 4 2 — Total $869 $12 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 473 672 5 years - 10 years 655 852 10 years - 15 years 389 377 15 years - 20 years 130 144 20 years+ 530 576 Total $2,177 $2,617 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $1,465 million, $1,024 million, and $1,427 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $29 million, $47 million, and $25 million, respectively, and gross losses of $17 million, $4 million, and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of December 31, 2021 was $576 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $526.3 $11.4 $4.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $519.6 million as of December 31, 2021 and $420.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.44 years, and an average maturity of approximately 7.58 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $163.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $183.8 $2.9 $29.9 $0.3 More than 12 months 39.5 1.8 — — Total $223.3 $4.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 91.7 113.1 5 years - 10 years 217.4 189.8 10 years - 15 years 146.0 81.4 15 years - 20 years 35.7 28.5 20 years+ 35.5 35.1 Total $526.3 $447.9 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $57.6 million, $94.5 million, and $110.6 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $2.5 million, $8.8 million, and $2.9 million, respectively, and gross losses of $0.6 million, $0.2 million, and $0.1 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $794.2 $31.3 $3.3 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $766.3 million as of December 31, 2021 and $581.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.30%, an average duration of approximately 6.83 years, and an average maturity of approximately 12.29 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $249.4 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $206.9 $1.4 $36.4 $0.5 More than 12 months 42.9 1.9 0.8 — Total $249.8 $3.3 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 157.8 117.0 5 years - 10 years 173.0 159.4 10 years - 15 years 123.0 101.2 15 years - 20 years 80.2 66.9 20 years+ 260.2 187.7 Total $794.2 $632.2 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $303.4 million, $159.7 million, and $186 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $6.8 million, $8.1 million, and $4.8 million, respectively, and gross losses of $4.1 million, $0.7 million, and $0.3 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $524.5 $11.8 $2.9 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $515.6 million as of December 31, 2021 and $398.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.33%, an average duration of approximately 7.33 years, and an average maturity of approximately 10.15 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $155.1 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $276.6 $2.3 $28.9 $0.8 More than 12 months 11.3 0.6 — — Total $287.9 $2.9 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 156.8 134.7 5 years - 10 years 161.8 141.5 10 years - 15 years 58.6 31.5 15 years - 20 years 1.9 5.3 20 years+ 145.4 115.8 Total $524.5 $427.7 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $513.8 million, $252.2 million, and $338.1 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $9.3 million, $11.5 million, and $5.4 million, respectively, and gross losses of $4.0 million, $0.6 million, and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit losses Entergy implemented ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, effective January 1, 2020. In accordance with the new standard, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an individual security is determined to be uncollectible it is written off against this allowance. Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities. As of December 31, 2021 and 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the years ended December 31, 2021 and 2020. Other-than-temporary impairments and unrealized gains and losses
Entergy Louisiana [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 14 to the financial statements, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. 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 year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $605 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $2,177 $65 $12 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $2 million as of December 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $2,125 million as of December 31, 2021 and $2,423 million as of December 31, 2020. As of December 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.74%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.55 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $770 $8 $187 $3 More than 12 months 99 4 2 — Total $869 $12 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 473 672 5 years - 10 years 655 852 10 years - 15 years 389 377 15 years - 20 years 130 144 20 years+ 530 576 Total $2,177 $2,617 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $1,465 million, $1,024 million, and $1,427 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $29 million, $47 million, and $25 million, respectively, and gross losses of $17 million, $4 million, and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of December 31, 2021 was $576 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $526.3 $11.4 $4.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $519.6 million as of December 31, 2021 and $420.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.44 years, and an average maturity of approximately 7.58 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $163.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $183.8 $2.9 $29.9 $0.3 More than 12 months 39.5 1.8 — — Total $223.3 $4.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 91.7 113.1 5 years - 10 years 217.4 189.8 10 years - 15 years 146.0 81.4 15 years - 20 years 35.7 28.5 20 years+ 35.5 35.1 Total $526.3 $447.9 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $57.6 million, $94.5 million, and $110.6 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $2.5 million, $8.8 million, and $2.9 million, respectively, and gross losses of $0.6 million, $0.2 million, and $0.1 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $794.2 $31.3 $3.3 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $766.3 million as of December 31, 2021 and $581.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.30%, an average duration of approximately 6.83 years, and an average maturity of approximately 12.29 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $249.4 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $206.9 $1.4 $36.4 $0.5 More than 12 months 42.9 1.9 0.8 — Total $249.8 $3.3 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 157.8 117.0 5 years - 10 years 173.0 159.4 10 years - 15 years 123.0 101.2 15 years - 20 years 80.2 66.9 20 years+ 260.2 187.7 Total $794.2 $632.2 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $303.4 million, $159.7 million, and $186 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $6.8 million, $8.1 million, and $4.8 million, respectively, and gross losses of $4.1 million, $0.7 million, and $0.3 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $524.5 $11.8 $2.9 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $515.6 million as of December 31, 2021 and $398.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.33%, an average duration of approximately 7.33 years, and an average maturity of approximately 10.15 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $155.1 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $276.6 $2.3 $28.9 $0.8 More than 12 months 11.3 0.6 — — Total $287.9 $2.9 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 156.8 134.7 5 years - 10 years 161.8 141.5 10 years - 15 years 58.6 31.5 15 years - 20 years 1.9 5.3 20 years+ 145.4 115.8 Total $524.5 $427.7 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $513.8 million, $252.2 million, and $338.1 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $9.3 million, $11.5 million, and $5.4 million, respectively, and gross losses of $4.0 million, $0.6 million, and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit losses Entergy implemented ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, effective January 1, 2020. In accordance with the new standard, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an individual security is determined to be uncollectible it is written off against this allowance. Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities. As of December 31, 2021 and 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the years ended December 31, 2021 and 2020. Other-than-temporary impairments and unrealized gains and losses
System Energy [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 14 to the financial statements, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million. 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, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant. Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity. Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. 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 year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $605 million. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $2,177 $65 $12 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $2 million as of December 31, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $2,125 million as of December 31, 2021 and $2,423 million as of December 31, 2020. As of December 31, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.74%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.55 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $770 $8 $187 $3 More than 12 months 99 4 2 — Total $869 $12 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 473 672 5 years - 10 years 655 852 10 years - 15 years 389 377 15 years - 20 years 130 144 20 years+ 530 576 Total $2,177 $2,617 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $1,465 million, $1,024 million, and $1,427 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $29 million, $47 million, and $25 million, respectively, and gross losses of $17 million, $4 million, and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of December 31, 2021 was $576 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts. The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $526.3 $11.4 $4.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $519.6 million as of December 31, 2021 and $420.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.28%, an average duration of approximately 6.44 years, and an average maturity of approximately 7.58 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $163.2 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $183.8 $2.9 $29.9 $0.3 More than 12 months 39.5 1.8 — — Total $223.3 $4.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 91.7 113.1 5 years - 10 years 217.4 189.8 10 years - 15 years 146.0 81.4 15 years - 20 years 35.7 28.5 20 years+ 35.5 35.1 Total $526.3 $447.9 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $57.6 million, $94.5 million, and $110.6 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $2.5 million, $8.8 million, and $2.9 million, respectively, and gross losses of $0.6 million, $0.2 million, and $0.1 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $794.2 $31.3 $3.3 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $766.3 million as of December 31, 2021 and $581.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.30%, an average duration of approximately 6.83 years, and an average maturity of approximately 12.29 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $249.4 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $206.9 $1.4 $36.4 $0.5 More than 12 months 42.9 1.9 0.8 — Total $249.8 $3.3 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 157.8 117.0 5 years - 10 years 173.0 159.4 10 years - 15 years 123.0 101.2 15 years - 20 years 80.2 66.9 20 years+ 260.2 187.7 Total $794.2 $632.2 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $303.4 million, $159.7 million, and $186 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $6.8 million, $8.1 million, and $4.8 million, respectively, and gross losses of $4.1 million, $0.7 million, and $0.3 million, respectively, related to available-for-sale securities were 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 December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $524.5 $11.8 $2.9 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $515.6 million as of December 31, 2021 and $398.4 million as of December 31, 2020. As of December 31, 2021, the available-for-sale debt securities had an average coupon rate of approximately 2.33%, an average duration of approximately 7.33 years, and an average maturity of approximately 10.15 years. The unrealized gains/(losses) recognized during the year ended December 31, 2021 on equity securities still held as of December 31, 2021 were $155.1 million. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $276.6 $2.3 $28.9 $0.8 More than 12 months 11.3 0.6 — — Total $287.9 $2.9 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 156.8 134.7 5 years - 10 years 161.8 141.5 10 years - 15 years 58.6 31.5 15 years - 20 years 1.9 5.3 20 years+ 145.4 115.8 Total $524.5 $427.7 During the years ended December 31, 2021, 2020, and 2019, proceeds from the dispositions of available-for-sale securities amounted to $513.8 million, $252.2 million, and $338.1 million, respectively. During the years ended December 31, 2021, 2020, and 2019, gross gains of $9.3 million, $11.5 million, and $5.4 million, respectively, and gross losses of $4.0 million, $0.6 million, and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit losses Entergy implemented ASU 2016-13, Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, effective January 1, 2020. In accordance with the new standard, Entergy estimates the expected credit losses for its available for sale securities based on the current credit rating and remaining life of the securities. To the extent an individual security is determined to be uncollectible it is written off against this allowance. Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities. As of December 31, 2021 and 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.4 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the years ended December 31, 2021 and 2020. Other-than-temporary impairments and unrealized gains and losses

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2021
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
Entergy Arkansas [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
Entergy Louisiana [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
Entergy Mississippi [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
Entergy New Orleans [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
Entergy Texas [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.
System Energy [Member]
Variable Interest Entity Disclosure	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. Entergy Arkansas, Entergy Louisiana, and System Energy consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies. Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. Although the principal amount was not due until June 2022, Entergy Gulf States Reconstruction Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. Although the principal amount was not due until August 2021, Entergy Arkansas Restoration Funding made principal payments on the bonds in 2020, after which the bonds were fully repaid. Entergy Arkansas Restoration Funding, LLC was then legally dissolved in January 2021. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds. Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. Although the principal amount was not due until September 2023, Entergy Louisiana Investment Recovery Funding made principal payments on the bonds in 2021, after which the bonds were fully repaid. See Note 5 to the financial statements for additional details regarding the investment recovery bonds. Entergy New Orleans Storm Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy New Orleans, is a variable interest entity, and Entergy New Orleans is the primary beneficiary. In July 2015, Entergy New Orleans Storm Recovery Funding issued storm cost recovery bonds to recover Entergy New Orleans’s Hurricane Isaac storm restoration costs, including carrying costs, the costs of funding and replenishing the storm recovery reserve, and up-front financing costs associated with the securitization. With the proceeds, Entergy New Orleans Storm Recovery Funding purchased from Entergy New Orleans the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy New Orleans balance sheet. The creditors of Entergy New Orleans do not have recourse to the assets or revenues of Entergy New Orleans Storm Recovery Funding, including the storm recovery property, and the creditors of Entergy New Orleans Storm Recovery Funding do not have recourse to the assets or revenues of Entergy New Orleans. Entergy New Orleans has no payment obligations to Entergy New Orleans Storm Recovery Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements. System Energy made payments on its lease, including interest, of $17.2 million in 2021, $17.2 million in 2020, and $17.2 million in 2019. The lessor is a bank acting in the capacity of owner trustee for the benefit of equity investors in the transaction pursuant to trust agreement entered solely for the purpose of facilitating the lease transaction. It is possible that System Energy may be considered as the primary beneficiary of the lessor, but it is unable to apply the authoritative accounting guidance with respect to this VIE because the lessor is not required to, and could not, provide the necessary financial information to consolidate the lessor. Because System Energy accounts for this leasing arrangement as a capital financing, however, System Energy believes that consolidating the lessor would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. System Energy believes, however, that the obligations recorded on the balance sheet materially represent its potential exposure to loss. AR Searcy Partnership, LLC, is a tax equity partnership that qualifies as a variable interest entity, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. See Note 14 to the financial statements for additional discussion on the establishment of AR Searcy Partnership, LLC and the acquisition of the Searcy Solar facility. The entity is a VIE because the membership interests do not give Entergy Arkansas or the third party tax equity investor substantive kick out rights typical of equity owners. Entergy Arkansas is the primary beneficiary of the partnership because it is the managing member and has the right to a majority of the operating income of the partnership. See Note 1 to the financial statements for further discussion on the presentation of the third party tax equity partner’s noncontrolling interest and the HLBV method of accounting used to account for Entergy Arkansas’s investment in AR Searcy Partnership, LLC. As of December 31, 2021, AR Searcy Partnership, LLC recorded assets equal to $140 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $107 million. Entergy has also reviewed various lease arrangements, power purchase agreements, including agreements for renewable power, and other agreements that represent variable interests in other legal entities which have been determined to be variable interest entities. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.

Transactions With Affiliates

Transactions With Affiliates	12 Months Ended
	Dec. 31, 2021
Entergy Arkansas [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.
Entergy Louisiana [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.
Entergy Mississippi [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.
Entergy New Orleans [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.
Entergy Texas [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.
System Energy [Member]
Transactions With Affiliates	TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Louisiana receives preferred membership interest distributions from Entergy Holdings Company. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0 Transactions with Equity Method Investees EWO Marketing, LLC, an indirect wholly-owned subsidiary of Entergy, paid capacity charges and gas transportation to RS Cogen in the amounts of $24 million in 2021, $26 million in 2020, and $24.5 million in 2019. Entergy’s operating transactions with its other equity method investees were not significant in 2021, 2020, or 2019.

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition	12 Months Ended
	Dec. 31, 2021
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
Entergy Arkansas [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
Entergy Louisiana [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
Entergy Mississippi [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
Entergy New Orleans [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
Entergy Texas [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.
System Energy [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Revenues from electric service and the sale of natural gas are recognized when services are transferred to the customer in an amount equal to what Entergy has the right to bill the customer because this amount represents the value of services provided to customers. Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673 The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees. Electric Revenues Entergy’s primary source of revenue is from retail electric sales sold under tariff rates approved by regulators in its various jurisdictions. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy’s Utility operating companies provide power to customers on demand throughout the month, measured by a meter located at the customer’s property. Approved rates vary by customer class due to differing requirements of the customers and market factors involved in fulfilling those requirements. Entergy issues monthly bills to customers at rates approved by regulators for power and related services provided during the previous billing cycle. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies record an estimate for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and market prices of power in the respective jurisdiction. The inputs are revised as needed to approximate actual usage and cost. Each month, estimated unbilled amounts are recorded as unbilled revenue and accounts receivable, and the prior month’s estimate is reversed. Price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the other. Entergy may record revenue based on rates that are subject to refund. Such revenues are reduced by estimated refund amounts when Entergy believes refunds are probable based on the status of rate proceedings as of the date financial statements are prepared. Because these refunds will be made through a reduction in future rates, and not as a reduction in bills previously issued, they are presented as other revenues in the table above. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy issues monthly bills to its affiliated customers equal to its actual operating costs plus a return on common equity approved by the FERC. Entergy’s Utility operating companies also sell excess power not needed for its own customers, primarily through transactions with MISO, a regional transmission organization that maintains functional control over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In the MISO market, Entergy offers its generation and bids its load into the market. MISO settles these offers and bids based on locational marginal prices. These represent pricing for energy at a given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO region. MISO evaluates each market participant’s energy offers and demand bids to economically and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing position. Natural Gas Entergy Louisiana and Entergy New Orleans also distribute natural gas to retail customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Gas transferred to customers is measured by a meter at the customer’s property. Entergy issues monthly invoices to customers at rates approved by regulators for the volume of gas transferred to date. Competitive Businesses Revenues The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power and capacity produced by its operating plants to wholesale customers. The majority of Entergy Wholesale Commodities’ 2021 revenues were from the Palisades nuclear power plant located in Michigan. Entergy issues monthly invoices to the counterparties for these electric sales at the respective contracted or ISO market rate of electricity and related services provided during the previous month. Almost all of the Palisades nuclear plant output is sold under a 15-year PPA with Consumers Energy, executed as part of the acquisition of the plant in 2007 and expiring in April 2022. Prices under the original PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. Entergy executed an additional PPA to cover the period from the expiration of the original PPA through final shutdown in May 2022, at a price of $24.14/MWh. Entergy issues monthly invoices to Consumers Energy for electric sales based on the actual output of electricity and related services provided during the previous month at the contract price. The PPA was at below-market prices at the time of the acquisition and Entergy amortizes a liability to revenue over the life of the agreement. The amount amortized each period is based upon the present value, calculated at the date of acquisition, of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $12 million in 2021, $11 million in 2020, and $10 million in 2019. Amounts to be amortized to revenue through the remaining life of the agreement will be approximately $5 million in 2022. Practical Expedients and Exceptions Entergy has elected not to disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less, or for revenue recognized in an amount equal to what Entergy has the right to bill the customer for services performed. Most of Entergy’s contracts, except in a few cases where there are defined minimums or stated terms, are on demand. This results in customer bills that vary each month based on an approved tariff and usage. Entergy imposes monthly or annual minimum requirements on some customers primarily as credit and cost recovery guarantees and not as pricing for unsatisfied performance obligations. These minimums typically expire after the initial term or when specified costs have been recovered. The minimum amounts are part of each month’s bill and recognized as revenue accordingly. Some of the subsidiaries within the Entergy Wholesale Commodities segment have operations and maintenance services contracts that have fixed components and terms longer than one year. The total fixed consideration related to these unsatisfied performance obligations, however, is not material to Entergy revenues. Recovery of Fuel Costs Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are based on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues. Allowance for doubtful accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded an increase in 2020 in its allowance for doubtful accounts, as shown below. The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

Schedule II - Valuation And Qua

Schedule II - Valuation And Qualifying Accounts	12 Months Ended
	Dec. 31, 2021
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY CORPORATION AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning of Period Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $117,794 $57,517 $106,703 $68,608 2020 $7,404 $111,687 $1,297 $117,794 2019 $7,322 $2,806 $2,724 $7,404 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.
Entergy Arkansas [Member]
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY ARKANSAS, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning of Period Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $18,334 $30,433 $35,695 $13,072 2020 $1,169 $17,307 $142 $18,334 2019 $1,264 $1,000 $1,095 $1,169 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.
Entergy Louisiana [Member]
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY LOUISIANA, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning of Period Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $45,693 $17,219 $33,681 $29,231 2020 $1,902 $44,542 $751 $45,693 2019 $1,813 $762 $673 $1,902 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.
Entergy Mississippi [Member]
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY MISSISSIPPI, LLC SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $19,527 $850 $13,168 $7,209 2020 $636 $19,081 $190 $19,527 2019 $563 $406 $333 $636 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.
Entergy New Orleans [Member]
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $17,430 $6,850 $10,998 $13,282 2020 $3,226 $14,204 $— $17,430 2019 $3,222 $316 $312 $3,226 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.
Entergy Texas [Member]
SEC Schedule, 12-09, Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	ENTERGY TEXAS, INC. AND SUBSIDIARIES SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS For the Years Ended December 31, 2021, 2020, and 2019 (In Thousands) Column A Column B Column C Column D Column E Other Balance at Additions Changes Balance Description Beginning Charged to Income Deductions (2) at End of Period Allowance for doubtful accounts 2021 $16,810 $2,166 $13,162 $5,814 2020 $471 $16,554 $215 $16,810 2019 $461 $321 $311 $471 Notes: (1) A portion of the charges to income are deferred as a regulatory asset. (2) Deductions represent write-offs of accounts receivable balances and are reduced by recoveries of amounts previously written off.

Summary Of Significant Accoun_2

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2021
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Equity method investments with disproportionate allocation of earnings and losses in relation to an investor's ownership interest	Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
Entergy Arkansas [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Equity method investments with disproportionate allocation of earnings and losses in relation to an investor's ownership interest	Partnership with Disproportionate Allocation of Earnings and Losses in Relation to an Investor’s Ownership Interest Entergy Arkansas, as managing member, controls a tax equity partnership with a third party tax equity investor and consolidates the partnership for financial reporting purposes. The limited liability company agreement with the tax equity investor stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Arkansas and the tax equity investor with the tax equity investor being allocated a significant portion of the tax attributes, earnings, and cash flows until it receives its target return, at which point the earnings and cash flows will primarily be allocated to Entergy Arkansas. Entergy Arkansas has the option to purchase, at a future date specified in the partnership agreement, the tax equity investor’s interests at the then-current fair market value, plus an amount that results in the tax equity investor reaching its target return, if needed. Because of this disproportionate allocation, Entergy Arkansas accounts for its earnings in the partnership using the HLBV method of accounting. Under the HLBV method, the amounts of income and loss attributable to both Entergy Arkansas and the tax equity investor reflect changes in the amount each would hypothetically receive at the balance sheet date under the respective liquidation provisions of the limited liability company agreement, assuming the net assets of the partnership were liquidated at book value, after consideration of contributions and
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
Entergy Louisiana [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
Entergy Mississippi [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
Entergy New Orleans [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
Entergy Texas [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.
System Energy [Member]
Use Of Estimates In Preparation Of Financial Statements	Use of Estimates in the Preparation of Financial Statements In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.
Revenues And Fuel Costs	Revenues and Fuel Costs See Note 19 to the financial statements for a discussion of Entergy’s and the Registrant Subsidiaries’ revenues and fuel costs.
Property, Plant, And Equipment	Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Electric plant includes the portion of Grand Gulf that was sold and leased back in a prior period. For financial reporting purposes, this sale and leaseback arrangement is reported as a financing transaction. Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7 Depreciation rates on average depreciable property for Entergy approximated 2.7% in 2021, 2.8% in 2020, and 2.8% in 2019. Included in these rates are the depreciation rates on average depreciable Utility property of 2.7% in 2021, 2.7% in 2020, and 2.6% in 2019, and the depreciation rates on average depreciable Entergy Wholesale Commodities property of 7.5% in 2021, 12.7% in 2020, and 18.3% in 2019. The depreciation rates for Entergy Wholesale Commodities reflect the significantly reduced remaining estimated operating lives associated with management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. The decreases in the depreciation rates in 2021 and 2020 for Entergy Wholesale Commodities are due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020. Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear fuel costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these capital additions. Non-utility property - at cost (less accumulated depreciation) for Entergy is reported net of accumulated depreciation of $200 million as of December 31, 2021 and $191 million as of December 31, 2020. Construction expenditures included in accounts payable is $723 million as of December 31, 2021 and $745 million as of December 31, 2020. Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189 Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1% Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $188.5 million as of December 31, 2021 and $179.8 million as of December 31, 2020. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2021 and $0.5 million as of December 31, 2020.
Jointly-Owned Generating Stations	Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Nuclear Refueling Outage Costs	Nuclear Refueling Outage Costs Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. Because the values of their long-lived assets were impaired, and their remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, charged nuclear refueling outage costs directly to expense when incurred because their undiscounted cash flows were insufficient to recover the carrying amount of these costs.
Allowance For Funds Used During Construction (AFUDC)	Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes	Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. In September 2019, Entergy Utility Holding Company, LLC and its regulated wholly-owned subsidiaries including Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, and Entergy New Orleans, LLC became eligible to join and joined the Entergy Corporation consolidated federal income tax group. These changes do not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “ Other Tax Matters - Tax Cuts and Jobs Act ” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.
Earnings Per Share	Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30 The calculation of diluted earnings per share excluded 1,013,320 options outstanding at December 31, 2021, 523,999 options outstanding at December 31, 2020, and 173,290 options outstanding at December 31, 2019 because they were antidilutive. In addition, as discussed further in Note 7 to the financial statements, at December 31, 2021, 1,158,917 shares under then outstanding forward sale agreements were not included in the calculation of diluted earnings per share because their effect would have been antidilutive.
Stock-Based Compensation Plans	Stock-based Compensation Plans Entergy grants stock options, restricted stock, performance units, and restricted stock unit awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stock-based compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over three years. Entergy accounts for forfeitures of stock-based compensation when they occur. Entergy recognizes all income tax effects related to share-based payments through the income statement.
Accounting For The Effects Of Regulation	Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet. An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets. Entergy Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, or its steam business, unless specific cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes	Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or returned to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.
Cash And Cash Equivalents	Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.
Securitization Recovery Trust Accounts	Securitization Recovery Trust Accounts The funds that Entergy New Orleans and Entergy Texas hold in their securitization recovery trust accounts are not classified as cash and cash equivalents or restricted cash and cash equivalents because of their nature, uses, and restrictions. These funds are classified as part of other current assets and other investments, depending on the timeframe within which the Registrant Subsidiary expects to use the funds.
Allowance For Doubtful Accounts	Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements. See Note 19 to the financial statements for further details on the allowance for doubtful accounts.
Investments	Investments Entergy records decommissioning trust funds on the balance sheet at their fair value. Unrealized gains and losses on investments in equity securities held by the nuclear decommissioning trust funds are recorded in earnings as they occur rather than in other comprehensive income. Because of the ability of the Registrant Subsidiaries to
Equity Method Investments	Equity Method Investments Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of the investee’s comprehensive earnings and losses in income and as an increase or decrease to the investment account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support.
Derivative Financial Instruments And Commodity Derivatives	Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.
Fair Values	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 other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net
Impairment Of Long-Lived Assets	Impairment of Long-lived Assets Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Because the values of the long-lived assets were impaired, and the remaining estimated operating lives significantly reduced, the Entergy Wholesale Commodities nuclear plants, except for Palisades, were charging additional expenditures for capital assets directly to expense when incurred. See Note 14 to the financial statements for further discussions of the impairments of the Entergy Wholesale Commodities nuclear plants.
River Bend AFUDC	River Bend AFUDC The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.
Reacquired Debt	Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed On Revenue-Producing Transactions	Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
New Accounting Pronouncements	New Accounting Pronouncements The accounting standard-setting process is ongoing and the FASB is currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial positions, or cash flows.

Summary Of Significant Accoun_3

Summary Of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for Entergy (including property under lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,632 $7,624 $8 $— Other 7,158 7,105 53 — Transmission 9,578 9,577 1 — Distribution 12,877 12,877 — — Other 2,910 2,905 — 5 Construction work in progress 1,512 1,511 1 — Nuclear fuel 577 563 14 — Property, plant, and equipment - net $42,244 $42,162 $77 $5 2020 Entergy Utility Entergy Wholesale Commodities Parent & Other (In Millions) Production Nuclear $7,526 $7,493 $33 $— Other 6,346 6,270 76 — Transmission 8,758 8,758 — — Distribution 10,805 10,805 — — Other 2,804 2,792 5 7 Construction work in progress 2,012 2,008 4 — Nuclear fuel 601 548 53 — Property, plant, and equipment - net $38,853 $38,674 $171 $7
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Schedule Of Earnings Per Share, Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of operations: For the Years Ended December 31, 2021 2020 2019 (In Millions, Except Per Share Data) $/share $/share $/share Net income attributable to Entergy Corporation $1,118.5 $1,388.3 $1,241.2 Basic shares and earnings per average common share 200.9 $5.57 200.1 $6.94 195.2 $6.36 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.02) 0.6 (0.02) Other equity plans 0.6 (0.02) 0.5 (0.02) 0.8 (0.03) Equity forwards — — — — 0.4 (0.01) Diluted shares and earnings per average common shares 201.9 $5.54 201.1 $6.90 197.0 $6.30
Entergy Arkansas [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Entergy Louisiana [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Entergy Mississippi [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Entergy New Orleans [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
Entergy Texas [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.
System Energy [Member]
Schedule Of Net Property, Plant, And Equipment	Net property, plant, and equipment for the Registrant Subsidiaries (including property under lease and associated accumulated amortization) by company and functional category, as of December 31, 2021 and 2020, is shown below: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,775 $3,941 $— $— $— $1,908 Other 931 3,631 882 411 1,250 — Transmission 2,065 4,237 1,383 114 1,743 35 Distribution 2,801 5,629 1,879 702 1,866 — Other 534 1,042 342 349 273 24 Construction work in progress 241 848 95 22 184 98 Nuclear fuel 182 209 — — — 171 Property, plant, and equipment - net $8,529 $19,537 $4,581 $1,598 $5,316 $2,236 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) Production Nuclear $1,622 $3,980 $— $— $— $1,891 Other 803 3,660 868 416 523 — Transmission 2,053 3,756 1,235 111 1,566 37 Distribution 2,666 4,130 1,651 576 1,782 — Other 506 984 325 326 273 26 Construction work in progress 234 667 135 12 880 60 Nuclear fuel 163 210 — — — 175 Property, plant, and equipment - net $8,047 $17,388 $4,214 $1,441 $5,023 $2,189
Schedule Of Depreciation Rates On Average Depreciable Property	Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy 2021 2.7% 2.4% 3.6% 3.2% 3.2% 1.9% 2020 2.6% 2.4% 3.5% 3.1% 3.1% 2.1% 2019 2.5% 2.4% 3.2% 3.2% 3.0% 2.1%
Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations	As of December 31, 2021, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows: Generating Stations Fuel Type Total Megawatt Capability (a) Ownership Investment Accumulated Depreciation (In Millions) Utility business: Entergy Arkansas - Independence Unit 1 Coal 822 31.50 % $143 $106 Independence Common Facilities Coal 15.75 % $43 $31 White Bluff Units 1 and 2 Coal 1,639 57.00 % $587 $390 Ouachita (b) Common Facilities Gas 66.67 % $173 $156 Union (c) Common Facilities Gas 25.00 % $29 $9 Entergy Louisiana - Roy S. Nelson Unit 6 Coal 521 40.25 % $294 $212 Roy S. Nelson Unit 6 Common Facilities Coal 19.57 % $21 $10 Big Cajun 2 Unit 3 Coal 540 24.15 % $151 $131 Big Cajun 2 Unit 3 Common Facilities Coal 8.05 % $5 $3 Ouachita (b) Common Facilities Gas 33.33 % $91 $78 Acadia Common Facilities Gas 50.00 % $21 $2 Union (c) Common Facilities Gas 50.00 % $59 $10 Entergy Mississippi - Independence Units 1 and 2 and Common Facilities Coal 1,246 25.00 % $286 $179 Entergy New Orleans - Union (c) Common Facilities Gas 25.00 % $29 $8 Entergy Texas - Roy S. Nelson Unit 6 Coal 521 29.75 % $208 $120 Roy S. Nelson Unit 6 Common Facilities Coal 14.47 % $7 $3 Big Cajun 2 Unit 3 Coal 540 17.85 % $113 $84 Big Cajun 2 Unit 3 Common Facilities Coal 5.95 % $4 $1 Montgomery County Unit 1 Gas 909 92.44 % $728 $18 System Energy - Grand Gulf (d) Unit 1 Nuclear 1,404 90.00 % $5,363 $3,317 Entergy Wholesale Commodities: Independence Unit 2 Coal 424 14.37 % $76 $55 Independence Common Facilities Coal 7.18 % $20 $14 Roy S. Nelson Unit 6 Coal 521 10.90 % $118 $69 Roy S. Nelson Unit 6 Common Facilities Coal 5.30 % $3 $1 (a) “Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. (b) Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. (c) Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. (d) Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Rate And Regulatory Matters (Ta

Rate And Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2021
Details Of Other Regulatory Assets	Entergy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $2,327.7 $3,027.5 Removal costs (Note 9) 1,488.8 893.8 Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators and Note 5 - Securitization Bonds ) 993.6 379.2 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 935.5 1,018.9 Retired electric and gas meters - recovered through retail rates as determined by retail regulators 179.4 192.1 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 133.1 105.7 Opportunity Sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 113.2 16.9 Unamortized loss on reacquired debt - recovered over term of debt 74.7 79.2 Retail rate deferrals - recovered through formula rates or rate riders as rates are redetermined by retail regulators 66.1 66.0 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.8 14.2 Other 123.1 125.9 Entergy Total $6,613.3 $6,076.5
Schedule of Regulatory Liabilities	Entergy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $1,993.3 $1,694.1 Louisiana Act 55 financing savings obligation (Note 3) (b) 127.4 144.3 Retail rate over-recovery - refunded through formula rate or rate riders as rates are redetermined annually 126.5 75.1 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Internal restructuring guaranteed tax credits 19.8 26.4 Deferred tax equity partnership earnings (Note 1) 18.1 — Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Advanced metering system (AMS) surcharge - return to customers dependent upon AMS spend 7.3 20.1 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 83.7 53.5 Entergy Total $2,643.8 $2,323.9
Entergy Louisiana [Member]
Details Of Other Regulatory Assets	Entergy Louisiana 2021 2020 (In Millions) Removal costs (Note 9) $848.2 $302.5 Storm damage costs, including hurricane costs - recovery expected through retail rates and securitization (Note 2 - Hurricane Ida and Storm Cost Recovery Filings with Retail Regulators ) 773.6 94.0 Pension & postretirement costs (Note 11 - Qualified Pension Plans and Non-Qualified Pension Plans ) (a) 592.7 799.4 Asset Retirement Obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 286.6 299.0 Retired electric meters - recovered over a 22-year period through July 2041 91.7 96.4 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 56.3 48.8 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 55.0 5.4 Unamortized loss on reacquired debt - recovered over term of debt 26.9 26.6 New nuclear generation development costs - recovery through formula rate plan December 2014 through November 2022 (b) 6.7 14.0 Other 39.0 40.0 Entergy Louisiana Total $2,776.7 $1,726.1
Schedule of Regulatory Liabilities	Entergy Louisiana 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $692.2 $567.7 Louisiana Act 55 financing savings obligation (Note 3) 127.4 144.3 Vidalia purchased power agreement (Note 8) (b) 106.2 115.7 Asset retirement obligation - return to customers dependent upon timing of decommissioning (Note 9) (a) 45.5 29.7 Retail rate rider over-recovery - refunded through rate riders as rates are determined annually 30.7 36.0 Business combination guaranteed customer benefits - returned to customers through retail rates and fuel rates December 2015 through November 2024 16.0 21.5 Derivative Instruments & Hedging Activities (Note 15) 11.4 — Other 13.2 3.4 Entergy Louisiana Total $1,042.6 $918.3
The Amount Of Deferred Fuel Costs, That Entergy Expects To Recover (Or Return To Customers) Through Fuel Mechanisms, Subject To Subsequent Regulatory Review	The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
Opportunity Sales Proceeding [Table Text Block]	Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33)
Entergy New Orleans [Member]
Details Of Other Regulatory Assets	Entergy New Orleans 2021 2020 (In Millions) Removal costs (Note 9) $91.7 $63.2 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 44.9 75.7 Storm damage costs, including hurricane costs - recovered through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy New Orleans Securitization Bonds - Hurricane Isaac ) 31.2 55.2 Retired meters - recovered over a 12-year period through July 2031 (b) 19.6 21.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 17.4 14.3 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 5.4 5.2 Unamortized loss on reacquired debt - recovered over term of debt 1.6 1.9 Other 36.8 29.6 Entergy New Orleans Total $248.6 $266.8
The Amount Of Deferred Fuel Costs, That Entergy Expects To Recover (Or Return To Customers) Through Fuel Mechanisms, Subject To Subsequent Regulatory Review	The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
Opportunity Sales Proceeding [Table Text Block]	Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33)
Entergy Texas [Member]
Details Of Other Regulatory Assets	Entergy Texas 2021 2020 (In Millions) Storm damage costs, including hurricane costs - recovered through securitization and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators and Note 5 - Entergy Texas Securitization Bonds - Hurricane Rita and Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav ) $143.1 $187.3 Removal costs (Note 9) 98.1 115.3 Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) 96.0 140.1 Retired electric meters - recovered over 13-year period through February 2032 23.7 26.0 Neches and Sabine costs - recovered over a 10-year period through September 2028 (Note 2 - Retail Rate Proceedings ) 16.4 18.8 Pension & postretirement benefits expense deferral - recovery period to be determined (Note 11 - Entergy Texas Reserve ) 14.6 3.8 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 11.7 12.9 Unamortized loss on reacquired debt - recovered over term of debt 9.8 10.5 Other 7.9 10.0 Entergy Texas Total $421.3 $524.7
Schedule of Regulatory Liabilities	Entergy Texas 2021 2020 (In Millions) Retail refunds - return to customers to be determined $22.8 $— Advanced metering system (AMS) surcharge - returned to customers dependent upon AMS spend 7.3 20.1 Income tax rate change - refunded through a rate rider (Note 2 - Retail Rate Proceedings ) 2.7 6.5 Transition to competition costs - returned to customers through rate riders when rates are redetermined periodically — 3.2 Other 4.3 2.5 Entergy Texas Total $37.1 $32.3
The Amount Of Deferred Fuel Costs, That Entergy Expects To Recover (Or Return To Customers) Through Fuel Mechanisms, Subject To Subsequent Regulatory Review	The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
Opportunity Sales Proceeding [Table Text Block]	Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33)
System Energy [Member]
Details Of Other Regulatory Assets	System Energy 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans and Other Postretirement Benefits ) (a) $160.3 $217.8 Asset retirement obligation - recovery dependent upon timing of decommissioning (Note 9) (a) 144.4 226.3 Removal costs - recovered through depreciation rates (Note 9) 89.7 92.9 Unamortized loss on reacquired debt - recovered over term of debt 1.1 2.0 System Energy Total $395.5 $539.0
Schedule of Regulatory Liabilities	System Energy 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $615.7 $529.0 Grand Gulf sale-leaseback - (Note 5 - Grand Gulf Sale-Leaseback Transactions ) 55.6 55.6 Entergy Arkansas ’ s accumulated accelerated Grand Gulf amortization - will be returned to customers when approved by the APSC and the FERC 44.4 44.4 Grand Gulf sale-leaseback accumulated deferred income taxes (a) 25.6 25.7 Entergy Mississippi ’ s accumulated accelerated Grand Gulf amortization - amortized and credited through the Unit Power Sales Agreement 3.6 10.7 System Energy Total $744.9 $665.4
Entergy Mississippi [Member]
Details Of Other Regulatory Assets	Entergy Mississippi 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $175.4 $242.7 Removal costs (Note 9) 136.8 107.3 Retail rate deferrals - returned through formula rates or rate riders as rates are redetermined annually 48.1 44.3 Attorney General litigation costs - recovered over a six-year period through March 2026 (b) 20.5 25.3 Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) 19.0 — Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 15.0 19.2 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost) 13.8 2.0 Unamortized loss on reacquired debt - recovered over term of debt 12.2 13.5 Asset retirement obligation - recovery dependent upon timing of dismantlement of non-nuclear power plants (Note 9) (a) 8.4 7.9 Other 13.2 5.1 Entergy Mississippi Total $462.4 $467.3
Schedule of Regulatory Liabilities	Entergy Mississippi 2021 2020 (In Millions) Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually $34.2 $14.2 Grand Gulf over-recovery - returned to customers through rate riders as rates are redetermined annually 15.1 1.0 Other — 0.6 Entergy Mississippi Total $49.3 $15.8
The Amount Of Deferred Fuel Costs, That Entergy Expects To Recover (Or Return To Customers) Through Fuel Mechanisms, Subject To Subsequent Regulatory Review	The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
Opportunity Sales Proceeding [Table Text Block]	Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33)
Entergy Arkansas [Member]
Details Of Other Regulatory Assets	Entergy Arkansas 2021 2020 (In Millions) Pension & postretirement costs (Note 11 - Qualified Pension Plans , Other Postretirement Benefits , and Non-Qualified Pension Plans ) (a) $640.0 $831.5 Asset retirement obligation - recovery dependent upon timing of decommissioning of nuclear units or dismantlement of non-nuclear power plants (Note 9) (a) 489.2 479.3 Removal costs (Note 9) 224.3 212.6 Opportunity sales - recovery will be determined after final order in proceeding (Note 2 - Entergy Arkansas Opportunity Sales Proceeding ) (b) 131.8 131.8 Retired electric meters - recovered over 15-year period through March 2034 43.4 46.9 Qualified Pension Settlement Cost Deferral - recovered over a 10-year period through July 2031 (Note 11 - Qualified Pension Settlement Cost ) 39.8 9.5 Storm damage costs - recovered either through securitization or retail rates (Note 5 - Entergy Arkansas Securitization Bonds ) 39.3 42.7 Deferred COVID-19 costs - recovery period to be determined (Note 2 - Retail Rate Proceedings ) (b) 32.6 10.5 Unamortized loss on reacquired debt - recovered over term of debt 23.1 24.7 ANO Fukushima and Flood Barrier costs - recovered through retail rates through February 2026 (Note 2 - Retail Rate Proceedings ) (b) 7.3 9.1 Retail rate deferrals - recovered through rate riders as rates are redetermined annually (b) 1.0 12.6 Other 17.9 21.2 Entergy Arkansas Total $1,689.7 $1,832.4
Schedule of Regulatory Liabilities	Entergy Arkansas 2021 2020 (In Millions) Unrealized gains on nuclear decommissioning trust funds (Note 16) (a) $685.4 $597.4 Internal restructuring guaranteed customer credits 19.8 26.4 Retail rate rider over-recovery - refunded through rate riders as rates are redetermined annually 18.9 19.6 Deferred tax equity partnership earnings (Note 1) 18.1 — Formula rate plan historical year rate adjustment (Note 2 - Retail Rate Proceedings ) — 43.5 Other 1.1 — Entergy Arkansas Total $743.3 $686.9
The Amount Of Deferred Fuel Costs, That Entergy Expects To Recover (Or Return To Customers) Through Fuel Mechanisms, Subject To Subsequent Regulatory Review	The table below shows the amount of deferred fuel costs as of December 31, 2021 and 2020 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review. 2021 2020 (In Millions) Entergy Arkansas (a) $177.6 $15.2 Entergy Louisiana (b) $213.5 $170.4 Entergy Mississippi $121.9 ($14.7) Entergy New Orleans (b) ($3.5) $6.2 Entergy Texas $48.3 ($85.4) (a) Includes $68.8 million in 2021 and $68.2 million in 2020 of fuel and purchased power costs whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. (b) Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.
Opportunity Sales Proceeding [Table Text Block]	Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018: Total refunds including interest Payment/(Receipt) (In Millions) Principal Interest Total Entergy Arkansas $68 $67 $135 Entergy Louisiana ($30) ($29) ($59) Entergy Mississippi ($18) ($18) ($36) Entergy New Orleans ($3) ($4) ($7) Entergy Texas ($17) ($16) ($33)

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy Corporation and Subsidiaries consist of the following: 2021 2020 2019 (In Thousands) Current: Federal ($5,003) $5,807 ($14,416) State (8,995) 57,939 6,535 Total (13,998) 63,746 (7,881) Deferred and non-current - net 205,891 (190,635) (155,956) Investment tax credit adjustments - net (519) 5,383 (5,988) Income taxes $191,374 ($121,506) ($169,825)
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 2020 2019 (In Thousands) Net income attributable to Entergy Corporation $1,118,492 $1,388,334 $1,241,226 Preferred dividend requirements of subsidiaries 227 18,319 17,018 Consolidated net income 1,118,719 1,406,653 1,258,244 Income taxes 191,374 (121,506) (169,825) Income before income taxes $1,310,093 $1,285,147 $1,088,419 Computed at statutory rate (21%) $275,120 $269,881 $228,568 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 79,273 60,087 61,791 Regulatory differences - utility plant items (57,556) (53,229) (45,336) Equity component of AFUDC (14,799) (25,080) (30,444) Amortization of investment tax credits (7,695) (8,386) (8,093) Flow-through / permanent differences (5,585) 11,099 (2,059) Amortization of excess ADIT (a) (66,478) (59,629) (205,614) Arkansas and Louisiana Rate Changes (b) (27,108) — — IRS audit adjustment (d) — (301,041) — Entergy Wholesale Commodities restructuring (c) — (9,223) (173,725) Stock compensation (e) — (25,591) — Charitable contribution (c) — — (19,101) Net operating loss recognition — — (41,427) Provision for uncertain tax positions 16,533 15,208 7,332 Valuation allowance (2,600) — 59,345 Other - net 2,269 4,398 (1,062) Total income taxes as reported $191,374 ($121,506) ($169,825) Effective Income Tax Rate 14.6 % (9.5 %) (15.6 %) (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020, and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Other Tax Matters - Entergy Wholesale Commodities Restructuring” below for discussion of the Entergy Wholesale Commodities restructuring in 2019, the ownership of Palisades restructuring in 2020, and the charitable contribution in 2019. (d) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (e) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Deferred tax liabilities: Plant basis differences - net ($6,136,563) ($4,795,422) Regulatory assets (930,244) (429,996) Nuclear decommissioning trusts/receivables (656,185) (1,188,235) Pension, net regulatory asset (322,788) (327,445) Combined unitary state taxes (7,255) (7,723) Unbilled/deferred revenues — (9,152) Accumulated storm damage provision (207,243) — Deferred fuel (85,310) (7,667) Other (341,450) (549,355) Total (8,687,038) (7,314,995) Deferred tax assets: Nuclear decommissioning liabilities 278,136 968,464 Regulatory liabilities 1,318,381 791,927 Pension and other post-employment benefits 208,128 278,486 Sale and leaseback 102,474 102,477 Compensation 79,798 89,279 Accumulated deferred investment tax credit 57,986 57,379 Provision for allowances and contingencies 82,286 71,598 Power purchase agreements 55,259 352,019 Unbilled/deferred revenues 26,683 — Net operating loss carryforwards 2,868,424 1,580,109 Capital losses and miscellaneous tax credits 11,111 21,291 Valuation allowance (325,239) (328,581) Other 200,032 230,291 Total 4,963,459 4,214,739 Non-current accrued taxes (including unrecognized tax benefits) (929,032) (1,185,227) Accumulated deferred income taxes and taxes accrued ($4,652,611) ($4,285,483)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Carryover Description Carryover Amount Year(s) of expiration Federal net operating losses before 1/1/2018 $6.2 billion 2023-2027 Federal net operating losses - 1/1/2018 forward $21.1 billion N/A State net operating losses $7.4 billion 2022-2041 State net operating losses with no expiration $16.7 billion N/A Federal and state charitable contributions $460.8 million 2022-2026 Miscellaneous federal and state credits $73.1 million 2022-2041
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows: 2021 2020 2019 (In Thousands) Gross balance at January 1 $5,699,339 $7,383,154 $7,181,482 Additions based on tax positions related to the current year 101,623 669,207 731,276 Additions for tax positions of prior years 33,419 98,591 151,628 Reductions for tax positions of prior years (74,413) (935,735) (681,232) Settlements — (1,515,878) — Gross balance at December 31 5,759,968 5,699,339 7,383,154 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (4,987,799) (4,710,214) (5,831,587) Cash paid to taxing authorities (60,000) (10,000) (10,000) Unrecognized tax benefits net of unused tax attributes, refund claims and payments (a) $712,169 $979,125 $1,541,567 (a) Potential tax liability above what is payable on tax returns
Entergy Arkansas [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3
Entergy Louisiana [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3
Entergy Mississippi [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3
Entergy New Orleans [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3
Entergy Texas [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3
System Energy [Member]
Tax Cuts and Jobs Act [Table Text Block]	The Registrant Subsidiaries’ December 31, 2021 and December 31, 2020 balance sheets reflect net regulatory liabilities for income taxes as follows: 2021 2020 (In Millions) Entergy Arkansas $432 $467 Entergy Louisiana $338 $479 Entergy Mississippi $212 $224 Entergy New Orleans $42 $59 Entergy Texas $171 $205 System Energy $113 $152 Excess ADIT is generally classified into two categories: 1) the portion that is subject to the normalization requirements of the TCJA, i.e., “protected”, and 2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes protected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $463 $490 Entergy Louisiana $669 $721 Entergy Mississippi $237 $248 Entergy New Orleans $56 $61 Entergy Texas $208 $215 System Energy $148 $173 Payment of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The Registrant Subsidiaries’ net regulatory liability for income taxes as of December 31, 2021 and December 31, 2020, includes unprotected excess ADIT as follows: 2021 2020 (In Millions) Entergy Arkansas $12 $11 Entergy Louisiana $148 $223 Entergy New Orleans $— $3 Entergy Texas $26 $54 System Energy $— $16 The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows for 2021 and 2020: 2021 2020 (In Millions) Entergy $88 $74 Entergy Arkansas $8 $8 Entergy Louisiana $33 $31 Entergy New Orleans $1 $6 Entergy Texas $28 $29 System Energy $18 $—
Income Tax Expenses From Continuing Operations	Income taxes for 2021, 2020, and 2019 for Entergy’s Registrant Subsidiaries consist of the following: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($20,285) ($24,053) ($5,868) ($6,724) ($189) $29,416 State 529 2,459 (11,506) (413) 1,261 (10,258) Total (19,756) (21,594) (17,374) (7,137) 1,072 19,158 Deferred and non-current - net 96,180 146,786 60,861 12,870 25,087 (25,229) Investment tax credit adjustments - net (1,229) (4,783) 1,836 203 (633) 4,094 Income taxes $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($44,627) $62,728 ($14,580) $293 ($5,603) $372,206 State (2,563) 4,457 (1,316) (303) 2,658 55,551 Total (47,190) 67,185 (15,896) (10) (2,945) 427,757 Deferred and non-current - net 96,195 (444,647) 43,640 (18,153) 6,619 (405,928) Investment tax credit adjustments - net (1,228) (4,862) (554) 13,956 (632) (1,286) Income taxes $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Current: Federal ($14,549) ($20,173) ($8,939) ($5,822) $16,035 $16,256 State (714) (735) 5,823 1,856 663 (2,831) Total (15,263) (20,908) (3,116) (3,966) 16,698 13,425 Deferred and non-current - net (30,278) 147,453 34,579 4,248 (69,963) 422 Investment tax credit adjustments - net (1,228) (4,922) (597) (96) (631) 1,502 Income taxes ($46,769) $121,623 $30,866 $186 ($53,896) $15,349
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2021, 2020, and 2019 are: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $298,484 $653,984 $166,834 $31,798 $228,824 $106,814 Income taxes 75,195 120,409 45,323 5,936 25,526 (1,977) Pretax income $373,679 $774,393 $212,157 $37,734 $254,350 $104,837 Computed at statutory rate (21%) $78,473 $162,623 $44,553 $7,924 $53,413 $22,016 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 19,633 41,030 9,305 2,579 1,553 5,385 Regulatory differences - utility plant items (16,078) (14,123) (8,133) (4,332) (2,115) (12,776) Equity component of AFUDC (3,207) (6,016) (1,701) (498) (2,077) (1,300) Amortization of investment tax credits (1,201) (4,729) 64 (56) (617) (1,155) Flow-through / permanent differences (814) (2,655) 124 1,559 (475) (1,235) Amortization of excess ADIT (a) (5,845) (24,323) — (1,028) (21,929) (13,354) Arkansas and Louisiana Rate Changes (b) 398 (6,126) 395 (1,569) 216 115 Non-taxable dividend income — (26,801) — — — — Provision for uncertain tax positions 353 300 465 1,200 (2,716) 200 Valuation Allowance 2,766 — — — — — Other - net 717 1,229 251 157 273 127 Total income taxes as reported $75,195 $120,409 $45,323 $5,936 $25,526 ($1,977) Effective Income Tax Rate 20.1 % 15.5 % 21.4 % 15.7 % 10.0 % (1.9 %) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $245,232 $1,082,352 $140,583 $49,338 $215,073 $99,131 Income taxes 47,777 (382,324) 27,190 (4,207) 3,042 20,543 Pretax income $293,009 $700,028 $167,773 $45,131 $218,115 $119,674 Computed at statutory rate (21%) $61,532 $147,006 $35,232 $9,478 $45,804 $25,132 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 16,256 38,182 6,917 2,606 1,460 5,524 Regulatory differences - utility plant items (8,034) (23,819) (7,441) (3,442) (7,673) (2,821) Equity component of AFUDC (3,154) (8,012) (1,412) (1,331) (9,255) (1,916) Amortization of investment tax credits (1,201) (4,811) (540) (61) (617) (1,155) Flow-through / permanent differences (2,219) 1,404 (102) 498 766 (421) Amortization of excess ADIT (a) (6,011) (26,293) 18 (4,564) (22,780) — Stock compensation (d) (4,952) (9,004) (2,763) (1,526) (2,842) (1,300) IRS audit adjustment (c) (6,351) (471,702) (3,768) (6,819) (2,091) (2,925) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions 1,200 300 800 800 — 300 Other - net 711 1,220 249 154 270 125 Total income taxes as reported $47,777 ($382,324) $27,190 ($4,207) $3,042 $20,543 Effective Income Tax Rate 16.3 % (54.6 %) 16.2 % (9.3 %) 1.4 % 17.2 % 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net income $262,964 $691,537 $119,925 $52,629 $159,397 $99,120 Income taxes (46,769) 121,623 30,866 186 (53,896) 15,349 Pretax income $216,195 $813,160 $150,791 $52,815 $105,501 $114,469 Computed at statutory rate (21%) $45,401 $170,764 $31,666 $11,091 $22,155 $24,039 Increases (reductions) in tax resulting from: State income taxes net of federal income tax effect 15,954 42,854 5,563 3,443 360 5,134 Regulatory differences - utility plant items (10,627) (19,421) (5,556) (1,532) (1,987) (6,213) Equity component of AFUDC (3,255) (15,545) (1,755) (2,088) (5,973) (1,829) Amortization of investment tax credits (1,201) (4,871) (160) (88) (617) (1,155) Flow-through / permanent differences 696 439 160 (741) 560 (500) Amortization of excess ADIT (a) (90,921) (28,531) 203 (11,724) (69,091) (5,550) Non-taxable dividend income — (26,795) — — — — Provision for uncertain tax positions (3,517) 1,519 500 1,672 430 1,300 Other - net 701 1,210 245 153 267 123 Total income taxes as reported ($46,769) $121,623 $30,866 $186 ($53,896) $15,349 Effective Income Tax Rate (21.6 %) 15.0 % 20.5 % 0.4 % (51.1 %) 13.4 % (a) See “ Other Tax Matters - Tax Cuts and Jobs Act ” below for discussion of the amortization of excess accumulated deferred income taxes (ADIT) in 2019, 2020 and 2021 and the tax legislation enactment in 2017. (b) See “ Arkansas and Louisiana Corporate Income Tax Rate Changes ” below for details. (c) See “ Income Tax Audits - 2014-2015 IRS Audit” below for discussion of the resolution of the audit in 2020. (d) See “ Other Tax Matters - Stock Compensation” below for discussion of excess tax deductions.
Significant Components Of Accumulated Deferred Income Taxes And Accrued Taxes	Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,158,523) ($3,429,473) ($681,968) ($192,660) ($654,252) ($433,874) Regulatory assets (226,687) (530,274) (34,799) (30,694) (45,470) (61,205) Nuclear decommissioning trusts/receivables (175,882) (186,382) — — — (153,610) Pension, net regulatory asset (92,881) (93,681) (22,253) (11,429) (19,914) (18,033) Deferred fuel (27,497) (13,686) (30,409) (1,600) (10,139) (49) Accumulated storm damage provision — (193,967) — — (13,276) — Other (77,820) (138,299) (29,108) (33,071) (2,526) (5,622) Total (1,759,290) (4,585,762) (798,537) (269,454) (745,577) (672,393) Deferred tax assets: Regulatory liabilities 310,256 634,184 59,418 36,057 55,022 224,036 Nuclear decommissioning liabilities 123,568 (909) 1 (433) 94 9,432 Pension and other post-employment benefits (26,577) 73,006 (7,793) (16,090) (18,793) (1,925) Sale and leaseback — — — — — 102,474 Accumulated deferred investment tax credit 7,518 30,666 2,723 4,391 1,958 10,729 Provision for allowances and contingencies 24,829 21,768 10,236 5,559 7,730 — Power purchase agreements — — 1,140 — (1,202) — Unbilled/deferred revenues 3,331 9,919 2,306 971 10,196 — Compensation 3,347 5,288 2,181 1,036 1,618 447 Net operating loss carryforwards 275,054 1,228,547 166,008 105,549 81 — Capital losses and miscellaneous tax credits — 5,141 1,258 10,977 883 1,958 Other 19,397 5,968 2,891 7,788 863 2 Total 740,723 2,013,578 240,369 155,805 58,450 347,153 Non-current accrued taxes (including unrecognized tax benefits) (397,634) 138,330 (161,929) (251,735) (5,369) (57,691) Accumulated deferred income taxes and taxes accrued ($1,416,201) ($2,433,854) ($720,097) ($365,384) ($692,496) ($382,931) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Deferred tax liabilities: Plant basis differences - net ($1,117,948) ($2,481,976) ($623,796) ($83,457) ($620,669) ($407,125) Regulatory assets (188,284) (95,135) (22,381) (20,276) (47,684) (56,496) Nuclear decommissioning trusts/receivables (156,123) (148,040) — — — (131,985) Pension, net funding (93,486) (95,854) (24,922) (11,564) (19,481) (20,330) Deferred fuel — (4,210) (1,706) (1,393) — (314) Other (54,753) (76,735) (27,565) (26,334) (141) (12,521) Total (1,610,594) (2,901,950) (700,370) (143,024) (687,975) (628,771) Deferred tax assets: Regulatory liabilities 273,774 218,278 56,022 31,248 47,991 163,534 Nuclear decommissioning liabilities 123,319 7,767 — (419) 121 29,916 Pension and other post-employment benefits (24,747) 72,724 (6,763) (13,997) (17,132) (1,344) Sale and leaseback — — — — — 102,477 Accumulated deferred investment tax credit 7,971 31,155 2,261 4,197 2,088 9,706 Provision for allowances and contingencies 22,179 7,071 16,799 24,529 (4,094) — Power purchase agreements 9,662 3,381 1,140 (5,324) (30,932) — Unbilled/deferred revenues 4,242 (23,382) 2,989 877 5,909 — Compensation 2,264 3,240 1,670 761 1,308 48 Net operating loss carryforwards 119,555 363,806 54,262 26,564 53,052 — Capital losses and miscellaneous tax credits — 9,309 — 12,317 — 7,014 Other 16,036 6,958 3,507 8,128 2,232 2 Total 554,255 700,307 131,887 88,881 60,543 311,353 Non-current accrued taxes (including unrecognized tax benefits) (229,784) 63,121 (78,191) (284,571) (11,990) (42,417) Accumulated deferred income taxes and taxes accrued ($1,286,123) ($2,138,522) ($646,674) ($338,714) ($639,422) ($359,835)
Entergy's Estimated Tax Attributes, Carryovers And Their Expiration Dates	The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2021 are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Federal net operating losses before 1/1/2018 $— billion $1.7 billion $— billion $0.9 billion $— billion $— billion Year(s) of expiration N/A 2035-2037 N/A 2037 N/A N/A Federal net operating losses - 1/1/2018 forward $4.5 billion $4.5 billion $2.1 billion $0.7 billion $2.6 billion $— billion Year(s) of expiration N/A N/A N/A N/A N/A N/A State net operating losses $4.8 billion $7.2 billion $2.3 billion $1.7 billion $— million $— million Year(s) of expiration 2023-2026 N/A 2038-2041 N/A N/A N/A Misc. federal credits $4.7 million $12.3 million $1.8 million $15.3 million $3.1 million $1.5 million Year(s) of expiration 2038-2041 2035-2041 2038-2041 2037-2041 2036-2041 2036-2041 State credits $— million $— million $1.3 million $—million $2.9 million $9 million Year(s) of expiration N/A N/A 2022-2025 N/A 2027 2022-2025
Reconciliation Of Unrecognized Tax Benefits	A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2021, 2020, and 2019 is as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2021 $1,364,635 $640,295 $549,717 $639,546 $521,932 $21,652 Additions based on tax positions related to the current year 30,419 13,437 684 1,050 32,616 1,753 Additions for tax positions of prior years 15,013 9,304 1,504 6 2,315 1,897 Reductions for tax positions of prior years (1,573) (58,408) (2,336) (1,105) (4,568) (1,946) Gross balance at December 31, 2021 1,408,494 604,628 549,569 639,497 552,295 23,356 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (992,643) (604,628) (388,728) (484,899) (540,694) (8,576) Unrecognized tax benefits net of unused tax attributes and payments $415,851 $— $160,841 $154,598 $11,601 $14,780 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2020 $1,341,242 $2,381,653 $566,287 $716,773 $21,406 $473,331 Additions based on tax positions related to the current year (a) 9,403 35,681 5,619 2,430 504,362 4,013 Additions for tax positions of prior years 13,400 10,508 1,156 294 799 4,606 Reductions for tax positions of prior years (11,346) (679,601) (24,173) (80,267) (5,559) (41,466) Settlements 11,936 (1,107,946) 828 316 924 (418,832) Gross balance at December 31, 2020 1,364,635 640,295 549,717 639,546 521,932 21,652 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,112,628) (640,295) (465,679) (451,922) (507,720) (7,413) Unrecognized tax benefits net of unused tax attributes and payments $252,007 $— $84,038 $187,624 $14,212 $14,239 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Gross balance at January 1, 2019 $1,298,662 $2,400,171 $508,765 $686,687 $17,802 $467,487 Additions based on tax positions related to the current year 84,335 28,705 68,594 40,676 2,312 5,496 Additions for tax positions of prior years 20,399 25,090 1,651 489 1,299 2,186 Reductions for tax positions of prior years (62,154) (72,313) (12,723) (11,079) (7) (1,838) Gross balance at December 31, 2019 1,341,242 2,381,653 566,287 716,773 21,406 473,331 Offsets to gross unrecognized tax benefits: Loss and tax credit carryovers (1,134,187) (1,573,257) (506,976) (445,430) (3,944) (8,392) Unrecognized tax benefits net of unused tax attributes and payments $207,055 $808,396 $59,311 $271,343 $17,462 $464,939 (a) The primary additions for Entergy Texas in 2020 are related to the mark-to-market treatment discussed in “ Other Tax Matters - Tax Accounting Methods
Summary Of Unrecognized Tax Benefits That Would Affect Effective Income Tax Rate	The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $262.1 $259.3 $203.3 Entergy Louisiana $66.3 $63.8 $556.3 Entergy Mississippi $51.7 $50.7 $1.9 Entergy New Orleans $228.6 $203.5 $242.7 Entergy Texas $2.6 $6.1 $5.7 System Energy $1.7 $0.5 $—
Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits	Accrued balances for the possible payment of interest related to unrecognized tax benefits are as follows: December 31, 2021 2020 2019 (In Millions) Entergy Arkansas $2.7 $2.3 $3.1 Entergy Louisiana $3.7 $3.4 $14.2 Entergy Mississippi $2.4 $1.9 $1.7 Entergy New Orleans $5.2 $3.9 $4.7 Entergy Texas $1.1 $0.9 $1.1 System Energy $12.1 $11.9 $14.5
Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits	Interest (net-of-tax) was recorded as follows: 2021 2020 2019 (In Millions) Entergy Arkansas $0.4 ($0.8) $1.4 Entergy Louisiana $0.3 ($10.8) ($3.7) Entergy Mississippi $0.5 $0.2 $0.5 Entergy New Orleans $1.3 ($0.8) $2.0 Entergy Texas $0.2 ($0.2) $0.2 System Energy $0.2 ($2.6) $1.3

Revolving Credit Facilities, _2

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Tables)	12 Months Ended
	Dec. 31, 2021
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Following is a summary of the borrowings outstanding and capacity available under the facility as of December 31, 2021. Capacity Borrowings Letters of Credit Capacity Available (In Millions) $3,500 $165 $6 $3,329
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million
Entergy Arkansas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million
Entergy Louisiana [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million
Entergy Mississippi [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Entergy New Orleans [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Entergy Texas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2021 as follows: Company Expiration Date Amount of Facility Interest Rate (a) Amount Drawn as of December 31, 2021 Letters of Credit Outstanding as of December 31, 2021 Entergy Arkansas April 2022 $25 million (b) 2.75% — — Entergy Arkansas June 2026 $150 million (c) 1.23% — — Entergy Louisiana June 2026 $350 million (c) 1.32% $125 million — Entergy Mississippi April 2022 $10 million (d) 1.60% — — Entergy Mississippi April 2022 $35 million (d) 1.60% — — Entergy Mississippi April 2022 $37.5 million (d) 1.60% — — Entergy New Orleans June 2024 $25 million (c) 1.73% — — Entergy Texas June 2026 $150 million (c) 1.60% — $1.3 million (a) The interest rate is the estimated interest rate as of December 31, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations	In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2021: Company Amount of Uncommitted Facility Letter of Credit Fee Letters of Credit Issued as of Entergy Arkansas $25 million 0.78% $8.5 million Entergy Louisiana $125 million 0.78% $15.0 million Entergy Mississippi $65 million 0.78% $9.3 million Entergy New Orleans $15 million 1.00% $1.0 million Entergy Texas $80 million 0.875% $79.6 million (a) As of December 31, 2021, letters of credit posted with MISO covered financial transmission right exposure of $0.2 million for Entergy Mississippi and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. (b) As of December 31, 2021, in addition to the $9.3 million MISO letter of credit, Entergy Mississippi has $1 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
System Energy [Member]
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $140 Entergy Louisiana $450 $— Entergy Mississippi $175 $— Entergy New Orleans $150 $— Entergy Texas $200 $80 System Energy $200 $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of December 31, 2021: Company Expiration Date Amount of Facility Weighted Average Interest Rate on Borrowings (a) Amount Outstanding as of December 31, 2021 (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.17% $4.8 Entergy Louisiana River Bend VIE June 2024 $105 1.15% $42.7 Entergy Louisiana Waterford VIE June 2024 $105 1.16% $39.6 System Energy VIE June 2024 $120 1.16% $36.1 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of December 31, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.17% Series M due December 2023 $40 million Entergy Arkansas VIE 1.84% Series N due July 2026 $90 million Entergy Louisiana River Bend VIE 2.51% Series V due June 2027 $70 million Entergy Louisiana Waterford VIE 3.22% Series I due December 2023 $20 million System Energy VIE 2.05% Series K due September 2027 $90 million

Long - Term Debt (Tables)

Long - Term Debt (Tables)	12 Months Ended
	Dec. 31, 2021
Schedule Of Long-Term Debt	Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2021 and 2020 consisted of: Type of Debt and Maturity Weighted Average Interest Rate December 31, 2021 Interest Rate Ranges at December 31, Outstanding at 2021 2020 2021 2020 (In Thousands) Mortgage Bonds 2021-2025 2.70% 0.62% - 5.59% 0.62% - 5.59% $5,228,000 $4,978,000 2026-2030 3.13% 1.50%- 4.44% 1.6% - 4.44% 3,965,000 3,835,000 2031-2041 3.31% 1.75% - 4.52% 1.75% - 4.52% 3,612,000 2,252,000 2044-2066 4.06% 2.65% - 5.5% 2.65% - 5.5% 6,980,000 6,380,000 Governmental Bonds (a) 2022-2044 2.43% 2.0% - 2.5% 2.375% - 3.5% 332,680 377,680 Securitization Bonds 2022-2027 3.31% 2.67% - 4.38% 2.04% - 5.93% 85,234 177,522 Variable Interest Entities Notes Payable (Note 4) 2021-2027 2.21% 1.84% - 3.22% 2.05% - 3.92% 310,000 450,000 Entergy Corporation Notes due July 2022 n/a 4.00% 4.00% 650,000 650,000 due September 2025 n/a 0.9% 0.9% 800,000 800,000 due September 2026 n/a 2.95% 2.95% 750,000 750,000 due June 2028 n/a 1.9% — 650,000 — due June 2030 n/a 2.80% 2.80% 600,000 600,000 due June 2031 n/a 2.40% — 650,000 — due June 2050 n/a 3.75% 3.75% 600,000 600,000 Entergy New Orleans Unsecured Term Loan due May 2022 n/a — 3.00% — 70,000 Entergy New Orleans Unsecured Term Loan due May 2023 n/a 2.50% — 70,000 — 5 Year Credit Facility (Note 4) n/a 1.60% 2.35% 165,000 165,000 Entergy Louisiana Credit Facility (Note 4) n/a 1.32% — 125,000 — Vermont Yankee Credit Facility (Note 4) n/a 1.67% 2.46% 139,000 139,000 Entergy Arkansas VIE Credit Facility (Note 4) n/a 1.17% 1.94% 4,800 12,200 Entergy Louisiana River Bend VIE Credit Facility (Note 4) n/a 1.15% 1.95% 42,700 18,900 Entergy Louisiana Waterford VIE Credit Facility (Note 4) n/a 1.16% 1.72% 39,600 39,300 System Energy VIE Credit Facility (Note 4) n/a 1.16% 1.63% 36,100 — Long-term DOE Obligation (b) — — — 192,115 192,018 Grand Gulf Sale-Leaseback Obligation n/a — — 34,321 34,336 Unamortized Premium and Discount - Net (8,273) 3,665 Unamortized Debt Issuance Costs (177,904) (160,420) Other 5,528 5,575 Total Long-Term Debt 25,880,901 22,369,776 Less Amount Due Within One Year 1,039,329 1,164,015 Long-Term Debt Excluding Amount Due Within One Year $24,841,572 $21,205,761 Fair Value of Long-Term Debt $27,061,171 $24,813,818 (a) Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by collateral mortgage bonds. (b) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Amount (In Thousands) 2022 $1,040,631 2023 $2,460,563 2024 $2,299,475 2025 $1,379,140 2026 $2,595,720
Entergy Arkansas [Member]
Schedule Of Long-Term Debt	2021 2020 (In Thousands) Entergy Arkansas Mortgage Bonds: 3.75% Series due February 2021 $— $350,000 3.05% Series due June 2023 250,000 250,000 3.7% Series due June 2024 375,000 375,000 3.5% Series due April 2026 600,000 600,000 4.00% Series due June 2028 350,000 350,000 4.95% Series due December 2044 250,000 250,000 4.20% Series due April 2049 350,000 350,000 2.65% Series due June 2051 675,000 675,000 3.35% Series due June 2052 400,000 — 4.875% Series due September 2066 410,000 410,000 Total mortgage bonds 3,660,000 3,610,000 Governmental Bonds (a): 2.375% Series due January 2021, Independence County (c) — 45,000 Total governmental bonds — 45,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.65% Series L due July 2021 — 90,000 3.17% Series M due December 2023 40,000 40,000 1.84% Series N due July 2026 90,000 — Credit Facility due June 2024, weighted avg rate 1.17% 4,800 12,200 Total variable interest entity notes payable and credit facility 134,800 142,200 Other: Long-term DOE Obligation (b) 192,115 192,018 Unamortized Premium and Discount – Net 2,776 6,938 Unamortized Debt Issuance Costs (32,803) (30,638) Other 1,974 1,989 Total Long-Term Debt 3,958,862 3,967,507 Less Amount Due Within One Year — 485,000 Long-Term Debt Excluding Amount Due Within One Year $3,958,862 $3,482,507 Fair Value of Long-Term Debt $4,176,577 $4,355,632
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—
Entergy Louisiana [Member]
Schedule Of Long-Term Debt	2021 2020 (In Thousands) Entergy Louisiana Mortgage Bonds: 4.80% Series due May 2021 $— $200,000 3.3% Series due December 2022 200,000 200,000 4.05% Series due September 2023 325,000 325,000 0.62% Series due November 2023 1,100,000 1,100,000 5.59% Series due October 2024 300,000 300,000 0.95% Series due October 2024 1,000,000 — 5.40% Series due November 2024 400,000 400,000 3.78% Series due April 2025 110,000 110,000 3.78% Series due April 2025 190,000 190,000 4.44% Series due January 2026 250,000 250,000 2.40% Series due October 2026 400,000 400,000 3.12% Series due September 2027 450,000 450,000 3.25% Series due April 2028 425,000 425,000 1.60% Series due December 2030 300,000 300,000 3.05% Series due June 2031 325,000 325,000 2.35% Series due June 2032 500,000 — 4.0% Series due March 2033 750,000 750,000 3.10% Series due June 2041 500,000 — 5.0% Series due July 2044 170,000 170,000 4.95% Series due January 2045 450,000 450,000 4.20% Series due September 2048 900,000 900,000 4.20% Series due April 2050 525,000 525,000 2.90% Series due March 2051 650,000 650,000 4.875% Series due September 2066 270,000 270,000 Total mortgage bonds 10,490,000 8,690,000 Governmental Bonds (a): 3.375% Series due September 2028, Louisiana Public Facilities Authority (c) — 83,680 3.50% Series due June 2030, Louisiana Public Facilities Authority (c) — 115,000 2.00% Series due June 2030, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 16,200 — 2.50% Series due April 2036, Louisiana Local Government Environmental Facilities and Community Development Authority (c) 182,480 — Total governmental bonds 198,680 198,680 Variable Interest Entity Notes Payable and Credit Facilities (Note 4): 3.92% Series H due February 2021 — 40,000 3.22% Series I due December 2023 20,000 20,000 2.51% Series V due June 2027 70,000 70,000 Credit Facility due June 2024, weighted avg rate 1.15% 42,700 18,900 Credit Facility due June 2024, weighted avg rate 1.16% 39,600 39,300 Total variable interest entity notes payable and credit facilities 172,300 188,200 Securitization Bonds: 2.04% Series Senior Secured due September 2023 — 10,980 Total securitization bonds — 10,980 Other: Credit Facility due June 2026, weighted avg rate 1.32% 125,000 — Unamortized Premium and Discount - Net (7,523) (2,863) Unamortized Debt Issuance Costs (67,665) (61,132) Other 3,554 3,586 Total Long-Term Debt 10,914,346 9,027,451 Less Amount Due Within One Year 200,000 240,000 Long-Term Debt Excluding Amount Due Within One Year $10,714,346 $8,787,451 Fair Value of Long-Term Debt $11,492,650 $10,258,294
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—
Entergy Mississippi [Member]
Schedule Of Long-Term Debt	2021 2020 (In Thousands) Entergy Mississippi Mortgage Bonds: 3.10% Series due July 2023 $250,000 $250,000 3.75% Series due July 2024 100,000 100,000 3.25% Series due December 2027 150,000 150,000 2.85% Series due June 2028 375,000 375,000 2.55% Series due December 2033 200,000 — 4.52% Series due December 2038 55,000 55,000 3.85% Series due June 2049 435,000 435,000 3.50% Series due June 2051 370,000 170,000 4.90% Series due October 2066 260,000 260,000 Total mortgage bonds 2,195,000 1,795,000 Other: Unamortized Premium and Discount – Net 5,853 3,685 Unamortized Debt Issuance Costs (20,864) (18,108) Total Long-Term Debt 2,179,989 1,780,577 Less Amount Due Within One Year — — Long-Term Debt Excluding Amount Due Within One Year $2,179,989 $1,780,577 Fair Value of Long-Term Debt $2,346,230 $2,021,432
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—
Entergy New Orleans [Member]
Schedule Of Long-Term Debt	2021 2020 (In Thousands) Entergy New Orleans Mortgage Bonds: 3.9% Series due July 2023 $100,000 $100,000 3.0% Series due March 2025 78,000 78,000 4.0% Series due June 2026 85,000 85,000 4.19% Series due November 2031 90,000 — 4.51% Series due September 2033 60,000 60,000 4.51% Series due November 2036 70,000 — 3.75% Series due March 2040 62,000 62,000 5.0% Series due December 2052 30,000 30,000 5.50% Series due April 2066 110,000 110,000 Total mortgage bonds 685,000 525,000 Securitization Bonds: 2.67% Series Senior Secured due June 2027 30,977 42,850 Total securitization bonds 30,977 42,850 Other: 3.0% Unsecured Term Loan due May 2022 — 70,000 2.5% Unsecured Term Loan due May 2023 70,000 — Payable to associated company due November 2035 10,911 12,529 Unamortized Premium and Discount – Net (58) (91) Unamortized Debt Issuance Costs (8,665) (8,055) Total Long-Term Debt 788,165 642,233 Less Amount Due Within One Year 1,326 1,618 Long-Term Debt Excluding Amount Due Within One Year $786,839 $640,615 Fair Value of Long-Term Debt $765,538 $620,634
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—
Entergy Texas [Member]
Schedule Of Long-Term Debt	2021 2020 (In Thousands) Entergy Texas Mortgage Bonds: 2.55% Series due June 2021 $— $125,000 4.10% Series due September 2021 — 75,000 1.50% Series due September 2026 130,000 — 3.45% Series due December 2027 150,000 150,000 4.0% Series due March 2029 300,000 300,000 1.75% Series due March 2031 600,000 600,000 4.5% Series due March 2039 400,000 400,000 5.15% Series due June 2045 250,000 250,000 3.55% Series due September 2049 475,000 475,000 Total mortgage bonds 2,305,000 2,375,000 Securitization Bonds: 5.93% Series Senior Secured, Series A due June 2022 — 17,478 4.38% Series Senior Secured, Series A due November 2023 54,257 106,214 Total securitization bonds 54,257 123,692 Other: Unamortized Premium and Discount - Net 13,556 14,064 Unamortized Debt Issuance Costs (18,665) (19,048) Total Long-Term Debt 2,354,148 2,493,708 Less Amount Due Within One Year — 200,000 Long-Term Debt Excluding Amount Due Within One Year $2,354,148 $2,293,708 Fair Value of Long-Term Debt $2,483,995 $2,765,193
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—
System Energy [Member]
Future Minimum Lease Payments Sale Leaseback Transactions	As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321
Schedule Of Long-Term Debt	2021 2020 (In Thousands) System Energy Mortgage Bonds: 4.1% Series due April 2023 $250,000 $250,000 2.14% Series due December 2025 200,000 200,000 Total mortgage bonds 450,000 450,000 Governmental Bonds (a): 2.5% Series due April 2022, Mississippi Business Finance Corp. 50,305 134,000 2.375% Series due June 2044, Mississippi Business Finance Corp. (c) 83,695 — Total governmental bonds 134,000 134,000 Variable Interest Entity Notes Payable and Credit Facility (Note 4): 3.42% Series J due April 2021 — 100,000 2.05% Series K due September 2027 90,000 90,000 Credit Facility due June 2024, weighted avg rate 1.16% 36,100 — Total variable interest entity notes payable and credit facility 126,100 190,000 Other: Grand Gulf Sale-Leaseback Obligation 34,321 34,336 Unamortized Premium and Discount – Net (108) (165) Unamortized Debt Issuance Costs (3,017) (2,897) Total Long-Term Debt 741,296 805,274 Less Amount Due Within One Year 50,329 100,015 Long-Term Debt Excluding Amount Due Within One Year $690,967 $705,259 Fair Value of Long-Term Debt $743,040 $840,540
Schedule Of Annual Long-Term Debt Maturities	The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2021, for the next five years are as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) 2022 $— $200,000 $— $1,326 $— $50,305 2023 $290,000 $1,445,000 $250,000 $171,306 $54,257 $250,000 2024 $379,800 $1,782,300 $100,000 $1,275 $— $36,100 2025 $— $300,000 $— $79,140 $— $200,000 2026 $690,000 $775,000 $— $85,720 $130,000 $—

Preferred Equity (Tables)

Preferred Equity (Tables)	12 Months Ended
	Dec. 31, 2021
Schedule Of Number Of Shares And Units Authorized And Outstanding And Dollar Value Of Preferred Stock	The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and noncontrolling interest for Entergy Corporation subsidiaries as of December 31, 2021 and 2020 are presented below. Shares/Units Shares/Units 2021 2020 2021 2020 2021 2020 Entergy Corporation (Dollars in Thousands) Utility: Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest: Entergy Utility Holding Company, LLC, 7.5% Series (a) 110,000 110,000 110,000 110,000 $107,425 $107,425 Entergy Utility Holding Company, LLC, 6.25% Series (b) 15,000 15,000 15,000 15,000 14,366 14,366 Entergy Utility Holding Company, LLC, 6.75% Series (c) 75,000 75,000 75,000 75,000 73,370 73,370 Entergy Texas, 5.375% Series 1,400,000 1,400,000 1,400,000 1,400,000 35,000 35,000 Entergy Texas, 5.10% Series (d) 150,000 — — — — — Entergy Arkansas Noncontrolling Interest — — — — 33,110 — Total Utility Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 1,750,000 1,600,000 1,600,000 1,600,000 263,271 230,161 Entergy Wholesale Commodities: Preferred Stock without sinking fund: Entergy Finance Holding, Inc. 8.75% (e) 250,000 250,000 250,000 250,000 24,249 24,249 Total Subsidiaries’ Preferred Stock or Preferred Membership Interests without sinking fund and Noncontrolling Interest 2,000,000 1,850,000 1,850,000 1,850,000 $287,520 $254,410 (a) In October 2015, Entergy Utility Holding Company, LLC issued 110,000 units of $1,000 liquidation value 7.5% Series A Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after January 1, 2036, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $2,575 thousand of preferred stock issuance costs. (b) In November 2017, Entergy Utility Holding Company, LLC issued 15,000 units of $1,000 liquidation value 6.25% Series B Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2038, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $634 thousand of preferred stock issuance costs. (c) In November 2018, Entergy Utility Holding Company, LLC issued 75,000 units of $1,000 liquidation value 6.75% Series C Preferred Membership Interests, all of which are outstanding as of December 31, 2021. The distributions are cumulative and payable quarterly. These units are redeemable on or after February 28, 2039, at Entergy Utility Holding Company, LLC’s option, at the fixed redemption price of $1,000 per unit. Dollar amount outstanding is net of $1,630 thousand of preferred stock issuance costs. (d) Currently, all shares are held by Entergy Corporation.
Entergy Texas [Member]
Schedule Of Number Of Shares And Units Authorized And Outstanding And Dollar Value Of Preferred Stock	The number of shares authorized and outstanding and dollar value of preferred stock for Entergy Texas as of December 31, 2021 and 2020 are presented below. Shares Call Price per 2021 2020 2021 2020 2021 Entergy Texas Preferred Stock (Dollars in Thousands) Without sinking fund: Cumulative, $25 par value: 5.375% Series (a) 1,400,000 1,400,000 $35,000 $35,000 $— 5.10% Series (b) 150,000 — 3,750 — $25.50 Total without sinking fund 1,550,000 1,400,000 $38,750 $35,000 (a) In September 2019, Entergy Texas issued $35 million of 5.375% Series A Preferred Stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. (b) In November 2021, Entergy Texas issued $3.75 million of 5.10% Series B Preferred Stock, a total of 150,000 shares with a liquidation value of $25 per share, all of which are outstanding and held by Entergy Corporation as of December 31, 2021. The dividends are cumulative and payable quarterly. The preferred stock is redeemable at Entergy Texas’s option at a fixed redemption price of $25.50 per share prior to November 1, 2026 and at a fixed redemption price of $25 per share on or after November 1, 2026.
Entergy Arkansas [Member]
Schedule of Noncontrolling Interest	The dollar value of noncontrolling interest for Entergy Arkansas as of December 31, 2021 and 2020 is presented below. 2021 2020 (Dollars in Thousands) Entergy Arkansas Noncontrolling Interest AR Searcy Partnership, LLC (a) $33,110 $— Total Noncontrolling Interest $33,110 $— (a) In December 2021, AR Searcy Partnership, LLC, a tax equity partnership between Entergy Arkansas and a tax equity investor, acquired the Searcy Solar facility. Entergy Arkansas, as the managing member, consolidates AR Searcy Partnership, LLC and the tax equity investor’s interest is shown as noncontrolling interest in the financial statements. Entergy Arkansas uses the HLBV method of accounting for income or loss allocation to the tax equity investor’s noncontrolling interest. See Note 1 to the financial statements for further discussion on the presentation of the tax equity investor’s noncontrolling interest and the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC.

Common Equity (Tables)

Common Equity (Tables)	12 Months Ended
	Dec. 31, 2021
Schedule of Common Stock and Treasury Stock Shares Activity Roll Forward	Common stock and treasury stock shares activity for Entergy for 2021, 2020, and 2019 is as follows: 2021 2020 2019 Common Treasury Shares Common Treasury Shares Common Treasury Shares Beginning Balance, January 1 270,035,180 69,790,346 270,035,180 70,886,400 261,587,009 72,530,866 Issuances: Equity Distribution Program 1,930,330 — — — — — Equity forwards settled — — — — 8,448,171 — Employee Stock-Based Compensation Plans — (461,903) — (1,076,511) — (1,624,358) Directors’ Plan — (16,117) — (19,543) — (20,108) Ending Balance, December 31 271,965,510 69,312,326 270,035,180 69,790,346 270,035,180 70,886,400
Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2021 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,439 130,371 (48,050) 83,760 Amounts reclassified from accumulated other comprehensive income (loss) (31,193) 65,558 (1,446) 32,919 Net other comprehensive income (loss) for the period (29,754) 195,929 (49,496) 116,679 Ending balance, December 31, 2021 ($1,035) ($338,647) $7,154 ($332,528) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the year ended December 31, 2020 by component: Cash flow Pension Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 60,928 (49,113) 41,354 53,169 Amounts reclassified from accumulated other comprehensive income (loss) (116,415) 71,609 (10,650) (55,456) Net other comprehensive income (loss) for the period (55,487) 22,496 30,704 (2,287) Ending balance, December 31, 2020 $28,719 ($534,576) $56,650 ($449,207)
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $147,554 Competitive business operating revenues Interest rate swaps (194) (194) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,485 147,360 Income taxes (8,292) (30,945) Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,193 $116,415 Pension and other postretirement liabilities Amortization of prior-service costs $20,947 $20,769 (a) Amortization of loss (88,838) (110,185) (a) Settlement loss (16,379) (243) (a) Total amortization and settlement loss (84,270) (89,659) Income taxes 18,712 18,050 Income taxes Total amortization and settlement loss (net of tax) ($65,558) ($71,609) Net unrealized investment gain (loss) Realized gain (loss) $2,289 $16,851 Interest and investment income Income taxes (843) (6,201) Income taxes Total realized investment gain (loss) (net of tax) $1,446 $10,650 Total reclassifications for the period (net of tax) ($32,919) $55,456 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.
Entergy Louisiana [Member]
Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2021: Pension and Other (In Thousands) Beginning balance, January 1, 2021 $4,327 Other comprehensive income (loss) before reclassifications 4,084 Amounts reclassified from accumulated other comprehensive income (loss) (133) Net other comprehensive income (loss) for the period 3,951 Ending balance, December 31, 2021 $8,278 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the year ended December 31, 2020: Pension and Other (In Thousands) Beginning balance, January 1, 2020 $4,562 Other comprehensive income (loss) before reclassifications 3,002 Amounts reclassified from accumulated other comprehensive income (loss) (3,237) Net other comprehensive income (loss) for the period (235) Ending balance, December 31, 2020 $4,327
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Louisiana for the years ended December 31, 2021 and 2020 are as follows: Amounts reclassified from AOCI Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service costs $4,920 $6,179 (a) Amortization of loss (2,322) (1,557) (a) Settlement loss (2,484) (243) (a) Total amortization 114 4,379 Income taxes 19 (1,142) Income taxes Total amortization (net of tax) 133 3,237 Total reclassifications for the period (net of tax) $133 $3,237 (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 11 to the financial statements for additional details.

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2021
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
Entergy Arkansas [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
Entergy Louisiana [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
Entergy Mississippi [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
Entergy New Orleans [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
Entergy Texas [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *
System Energy [Member]
Maximum Amounts Of Possible Assessments Per Occurrence	Effective April 1, 2021, the maximum amounts of such possible assessments per occurrence were as follows: Assessments (In Millions) Utility: Entergy Arkansas $27.6 Entergy Louisiana $49.2 Entergy Mississippi $0.11 Entergy New Orleans $0.11 Entergy Texas N/A System Energy $21.4 Entergy Wholesale Commodities N/A *

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2021
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
Entergy Arkansas [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
Entergy Louisiana [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
Entergy Mississippi [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
Entergy New Orleans [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
Entergy Texas [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.
System Energy [Member]
Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates	In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs expected to be recovered in rates: December 31, 2021 2020 (In Millions) Entergy Arkansas $224.3 $212.6 Entergy Louisiana $848.2 $302.5 Entergy Mississippi $136.8 $107.3 Entergy New Orleans $91.7 $63.2 Entergy Texas $98.1 $115.3 System Energy $89.7 $92.9
Cumulative decommissioning and retirement cost liabilities and expenses	The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2021 and 2020 by Entergy were as follows: Liabilities as Accretion Spending Dispositions Liabilities as (In Millions) Entergy $6,469.5 $317.9 ($33.2) ($1,997.1) $4,757.1 Utility Entergy Arkansas 1,314.2 77.7 — (1.5) 1,390.4 Entergy Louisiana 1,573.3 79.9 — — 1,653.2 Entergy Mississippi 9.8 0.5 — — 10.3 Entergy New Orleans 3.8 0.2 — — 4.0 Entergy Texas 8.1 0.4 — — 8.5 System Energy 968.9 38.7 — — 1,007.6 Entergy Wholesale Commodities Big Rock Point 41.1 3.4 (2.5) — 42.0 Indian Point 1 246.6 8.8 (1.3) (254.1) (b) — Indian Point 2 839.8 28.9 (25.1) (843.6) (b) — Indian Point 3 869.4 29.1 (0.6) (897.9) (b) — Palisades 594.1 50.1 (3.8) — 640.4 Other (a) 0.5 0.1 — — 0.6 Liabilities as Accretion Spending Liabilities as (In Millions) Entergy $6,159.2 $394.6 ($84.3) $6,469.5 Utility Entergy Arkansas 1,242.6 73.3 (1.7) 1,314.2 Entergy Louisiana 1,497.3 76.0 — 1,573.3 Entergy Mississippi 9.7 0.6 (0.5) 9.8 Entergy New Orleans 3.5 0.3 — 3.8 Entergy Texas 7.6 0.5 — 8.1 System Energy 931.7 37.2 — 968.9 Entergy Wholesale Commodities Big Rock Point 40.3 3.3 (2.5) 41.1 Indian Point 1 238.6 20.4 (12.4) 246.6 Indian Point 2 829.0 69.4 (58.6) 839.8 Indian Point 3 808.4 67.4 (6.4) 869.4 Palisades 549.8 46.4 (2.1) 594.1 Other (a) 0.5 — — 0.5 (a) See “ Coal Combustion Residuals ” below for additional discussion regarding the asset retirement obligations related to coal combustion residuals management. (b) See Note 14 to the financial statements for discussion of the sale of the Indian Point Energy Center to Holtec International in May 2021.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Lease, Cost [Table Text Block]	Entergy incurred the following total lease costs for the years ended December 31, 2021 and 2020: 2021 2020 (In Thousands) Operating lease cost $69,067 $67,471 Finance lease cost: Amortization of right-of-use assets $12,483 $12,180 Interest on lease liabilities $2,845 $2,884
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of December 31, 2021 and 2020: 2021 2020 (In Thousands) Current liabilities: Operating leases $ 59,437 $ 59,004 Finance leases $ 12,988 $ 11,921 Non-current liabilities: Operating leases $ 152,363 $ 170,980 Finance leases $ 59,320 $ 52,803
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of Entergy at December 31, 2021 and 2020: 2021 2020 Weighted average remaining lease terms: Operating leases 4.44 4.82 Finance leases 6.18 6.34 Weighted average discount rate: Operating leases 3.37 % 3.58 % Finance leases 3.96 % 4.42 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for Entergy as of December 31, 2021 are as follows: Year Operating Leases Finance Leases (In Thousands) 2022 $65,270 $15,312 2023 55,527 14,611 2024 48,281 13,296 2025 28,174 11,913 2026 15,864 10,061 Years thereafter 14,531 15,756 Minimum lease payments 227,647 80,949 Less: amount representing interest 15,847 8,640 Present value of net minimum lease payments $211,800 $72,309
Entergy Arkansas [Member]
Lease, Assets [Table Text Block]	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719
Lease, Cost [Table Text Block]	The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583
Entergy Louisiana [Member]
Lease, Assets [Table Text Block]	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719
Lease, Cost [Table Text Block]	The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583
Entergy Mississippi [Member]
Lease, Assets [Table Text Block]	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719
Lease, Cost [Table Text Block]	The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583
Entergy New Orleans [Member]
Lease, Assets [Table Text Block]	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719
Lease, Cost [Table Text Block]	The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583
Entergy Texas [Member]
Lease, Assets [Table Text Block]	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021 and 2020 are the following amounts: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 Operating leases $56,099 $46,443 $16,831 $5,480 $14,986 Finance leases $15,043 $19,007 $9,114 $4,023 $7,583 2020 Operating leases $55,840 $43,189 $16,538 $5,222 $14,738 Finance leases $12,447 $16,425 $7,452 $3,428 $5,719
Lease, Cost [Table Text Block]	The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $15,087 $14,368 $7,018 $1,745 $5,370 Finance lease cost: Amortization of right-of-use assets $2,860 $3,938 $1,766 $731 $1,493 Interest on lease liabilities $432 $607 $270 $124 $214 The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy Entergy Texas (In Thousands) Operating lease cost $14,344 $13,944 $6,584 $1,443 $4,870 Finance lease cost: Amortization of right-of-use assets $2,693 $4,097 $1,627 $712 $1,340 Interest on lease liabilities $408 $597 $254 $120 $196
Lease, Liabilities [Table Text Block]	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $12,695 $12,520 $5,866 $1,491 $4,489 Finance leases $2,964 $4,001 $1,843 $812 $1,476 Non-current liabilities: Operating leases $43,420 $33,931 $10,976 $3,994 $10,505 Finance leases $12,079 $15,006 $7,271 $3,211 $6,107 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities: Operating leases $11,942 $11,934 $5,738 $1,406 $4,277 Finance leases $2,660 $3,821 $1,644 $686 $1,327 Non-current liabilities: Operating leases $43,914 $31,260 $10,867 $3,819 $10,469 Finance leases $9,788 $12,603 $5,808 $2,741 $4,392
Lease, Terms and Discount Rate [Table Text Block]	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2021: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.13 4.65 5.36 5.35 3.94 Finance leases 5.89 5.57 5.63 5.94 5.97 Weighted average discount rate: Operating leases 3.10 % 2.93 % 3.00 % 2.99 % 3.04 % Finance leases 2.80 % 3.08 % 2.87 % 3.03 % 2.79 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2020: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas Weighted average remaining lease terms: Operating leases 5.74 4.72 5.30 5.78 4.30 Finance leases 5.60 5.20 5.44 5.69 5.39 Weighted average discount rate: Operating leases 3.34 % 3.11 % 3.43 % 3.09 % 3.07 % Finance leases 3.18 % 3.33 % 3.22 % 3.35 % 3.22 %
Lease, Maturity [Table Text Block]	Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2021 are as follows: Operating Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $14,180 $13,706 $6,280 $1,682 $4,888 2023 12,713 11,791 4,181 1,441 4,449 2024 11,150 9,618 3,174 1,182 3,427 2025 9,292 6,694 2,168 773 1,933 2026 7,314 4,081 827 398 771 Years thereafter 5,892 3,574 1,924 601 423 Minimum lease payments 60,541 49,464 18,554 6,077 15,891 Less: amount representing interest 4,425 3,013 1,711 592 898 Present value of net minimum lease payments $56,116 $46,451 $16,843 $5,485 $14,993 Finance Leases Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2022 $3,319 $4,481 $2,054 $854 $1,637 2023 3,100 4,231 1,971 814 1,532 2024 2,791 3,671 1,783 712 1,382 2025 2,449 3,122 1,529 621 1,256 2026 2,018 2,367 1,202 545 1,016 Years thereafter 2,477 2,613 1,220 673 1,296 Minimum lease payments 16,154 20,485 9,759 4,219 8,119 Less: amount representing interest 1,111 1,478 645 196 536 Present value of net minimum lease payments $15,043 $19,007 $9,114 $4,023 $7,583
System Energy [Member]
Future Minimum Lease Payments Sale Leaseback Transactions	As of December 31, 2021, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal: Amount (In Thousands) 2022 $17,188 2023 17,188 2024 17,188 2025 17,188 2026 17,188 Years thereafter 171,875 Total 257,815 Less: Amount representing interest 223,494 Present value of net minimum lease payments $34,321

Retirement, Other Postretirem_2

Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Tables)	12 Months Ended
	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy Corporation and its subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components: 2021 2020 2019 (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $165,278 $161,487 $134,193 Interest cost on projected benefit obligation 191,107 239,614 293,114 Expected return on assets (424,572) (414,273) (414,947) Recognized net loss 334,124 350,010 241,117 Settlement charges 205,878 36,946 23,492 Net periodic pension costs $471,815 $373,784 $276,969 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net (gain)/loss ($448,532) $483,653 $614,600 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (334,124) (358,473) (241,117) Settlement charge (205,878) (36,946) (23,492) Total ($988,534) $88,234 $349,991 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($516,719) $462,018 $626,960
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Consolidated Balance Sheets for Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $9,143,652 $8,406,203 Service cost 165,278 161,487 Interest cost 191,107 239,614 Actuarial (gain)/ loss (158,276) 969,609 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Balance at December 31 $8,409,620 $9,143,652 Change in Plan Assets Fair value of assets at January 1 $6,854,426 $6,271,160 Actual return on plan assets 714,827 900,229 Employer contributions 355,998 316,298 Benefits paid (including settlement lump sum benefit payments of ($553,576) in 2021 and ($84,754) in 2020) (932,141) (633,261) Fair value of assets at December 31 $6,993,110 $6,854,426 Funded status ($1,416,510) ($2,289,226) Amount recognized in the balance sheet Non-current liabilities ($1,416,510) ($2,289,226) Amount recognized as a regulatory asset Net loss $2,214,390 $2,926,670 Amount recognized as AOCI (before tax) Net loss $449,756 $726,010
Reclassification Out of Accumulated Other Comprehensive Income, Amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2021: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $21,151 ($204) $20,947 Amortization of loss (84,661) (1,983) (2,194) (88,838) Settlement loss (12,001) — (4,378) (16,379) ($96,662) $19,168 ($6,776) ($84,270) Entergy Louisiana Amortization of prior service cost $— $4,920 $— $4,920 Amortization of loss (2,681) 364 (5) (2,322) Settlement loss (2,478) — (6) (2,484) ($5,159) $5,284 ($11) $114 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2020: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $21,000 ($231) $20,769 Amortization of loss (105,853) (1,006) (3,326) (110,185) Settlement loss (243) — — (243) ($106,096) $19,994 ($3,557) ($89,659) Entergy Louisiana Amortization of prior service cost $— $6,179 $— $6,179 Amortization of loss (2,001) 447 (3) (1,557) Settlement loss (243) — — (243) ($2,244) $6,626 ($3) $4,379
Target Asset Allocation	Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2021 and 2020 and the target asset allocation and ranges for 2021 are as follows: Pension Asset Allocation Target Range Actual 2021 Actual 2020 Domestic Equity Securities 39% 32% to 46% 40% 38% International Equity Securities 19% 15% to 23% 20% 19% Fixed Income Securities 42% 39% to 45% 40% 42% Other 0% 0% to 10% 0% 1% Postretirement Asset Allocation Non-Taxable and Taxable Target Range Actual 2021 Actual 2020 Domestic Equity Securities 25% 20% to 30% 28% 29% International Equity Securities 17% 12% to 22% 17% 18% Fixed Income Securities 58% 53% to 63% 55% 53% Other 0% 0% to 5% 0% 0%
Investments Held For Qualified Pension And Other Postretirement Plans Measured At Fair Value	The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2021, and December 31, 2020, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate. Qualified Defined Benefit Pension Plan Trusts 2021 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Corporate stocks: Preferred $16,231 (b) $— $— $16,231 Common 1,001,169 (b) — — 1,001,169 Common collective trusts (c) 3,123,111 Fixed income securities: U.S. Government securities — 627,148 (a) — 627,148 Corporate debt instruments — 966,616 (a) — 966,616 Registered investment companies (e) 92,347 (d) 3,004 (d) — 1,129,070 Other — 68,886 (f) — 68,886 Other: Insurance company general account (unallocated contracts) — 5,961 (g) — 5,961 Total investments $1,109,747 $1,671,615 $— $6,938,192 Cash 123,153 Other pending transactions 11,125 Less: Other postretirement assets included in total investments (79,360) Total fair value of qualified pension assets $6,993,110 2020 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Corporate stocks: Preferred $15,756 (b) $— $— $15,756 Common 1,031,213 (b) — — 1,031,213 Common collective trusts (c) 2,958,767 Fixed income securities: U.S. Government securities — 731,319 (a) — 731,319 Corporate debt instruments — 1,029,370 (a) — 1,029,370 Registered investment companies (e) 81,800 (d) 3,076 (d) — 1,128,107 Other 156 (f) 56,323 (f) — 56,479 Other: Insurance company general account (unallocated contracts) — 6,253 (g) — 6,253 Total investments $1,128,925 $1,826,341 $— $6,957,264 Cash 2,316 Other pending transactions (29,121) Less: Other postretirement assets included in total investments (76,033) Total fair value of qualified pension assets $6,854,426 Other Postretirement Trusts 2021 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Common collective trust (c) $312,594 Fixed income securities: U.S. Government securities 62,240 (b) 89,951 (a) — 152,191 Corporate debt instruments — 152,562 (a) — 152,562 Registered investment companies 28,450 (d) — — 28,450 Other — 72,059 (f) — 72,059 Total investments $90,690 $314,572 $— $717,856 Other pending transactions (25,897) Plus: Other postretirement assets included in the investments of the qualified pension trust 79,360 Total fair value of other postretirement assets $771,319 2020 Level 1 Level 2 Level 3 Total (In Thousands) Equity securities: Common collective trust (c) $315,191 Fixed income securities: U.S. Government securities 46,498 (b) 97,604 (a) — 144,102 Corporate debt instruments — 147,287 (a) — 147,287 Registered investment companies 16,965 (d) — — 16,965 Other — 60,219 (f) — 60,219 Total investments $63,463 $305,110 $— $683,764 Other pending transactions (21,931) Plus: Other postretirement assets included in the investments of the qualified pension trust 76,033 Total fair value of other postretirement assets $737,866 (a) Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes. (b) Common stocks, certain preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices. (c) The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. (d) Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities and estimate fair value using net asset value per share. (e) Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. (f) The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes and quoted market values. (g) The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.
Estimated Future Benefit Payments	Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefit obligations at December 31, 2021, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for Entergy Corporation and its subsidiaries will be as follows: Estimated Future Benefits Payments Qualified Pension Non-Qualified Pension Other Postretirement (before Medicare Subsidy) Estimated Future Medicare D Subsidy Receipts (In Thousands) Year(s) 2022 $550,204 $26,336 $72,400 $70 2023 $542,753 $24,710 $72,220 $27 2024 $549,913 $21,230 $71,506 $34 2025 $530,406 $36,210 $70,148 $34 2026 $525,278 $14,377 $68,744 $39 2027 - 2031 $2,527,735 $52,967 $328,634 $222
Actuarial Assumptions Used In Determining Pension And Other Postretirement Benefit Obligation	The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2021 and 2020 were as follows: 2021 2020 Weighted-average discount rate: Qualified pension 2.99% - 3.08% Blended 3.05% 2.60% - 2.83% Blended 2.77% Other postretirement 2.94% 2.62% Non-qualified pension 2.11% 1.61% Weighted-average rate of increase in future compensation levels 3.98% - 4.40% 3.98% - 4.40% Interest crediting rate 2.60% 2.60% Assumed health care trend rate: Pre-65 5.65% 5.87% Post-65 5.90% 6.31% Ultimate rate 4.75% 4.75% Year ultimate rate is reached and beyond: Pre-65 2032 2030 Post-65 2032 2028
Actuarial Assumptions Used In Determining Net Periodic And Other Postretirement Benefit Obligation	The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2021, 2020, and 2019 were as follows: 2021 2020 2019 Weighted-average discount rate: Qualified pension: Service cost 2.81% 3.42% 4.57% Interest cost 2.08% 2.99% 4.15% Other postretirement: Service cost 2.98% 3.27% 4.62% Interest cost 1.86% 2.41% 4.01% Non-qualified pension: Service cost 1.48% 2.71% 3.94% Interest cost 2.14% 2.25% 3.46% Weighted-average rate of increase in future compensation levels 3.98% - 4.40% 3.98% - 4.40% 3.98% Expected long-term rate of return on plan assets: Pension assets 6.75% 7.00% 7.25% Other postretirement non-taxable assets 6.00% - 6.75% 6.25% - 7.25% 6.50% - 7.50% Other postretirement taxable assets 5.00% 5.25% 5.50% Assumed health care trend rate: Pre-65 5.87% 6.13% 6.59% Post-65 6.31% 6.25% 7.15% Ultimate rate 4.75% 4.75% 4.75% Year ultimate rate is reached and beyond: Pre-65 2030 2027 2027 Post-65 2028 2027 2026
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy Corporation’s and its subsidiaries’ total 2021, 2020, and 2019 other postretirement benefit costs, including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income, included the following components: 2021 2020 2019 (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $26,578 $24,500 $18,699 Interest cost on accumulated postretirement benefit obligation (APBO) 21,278 28,597 47,901 Expected return on assets (43,220) (40,880) (38,246) Amortization of prior service credit (33,069) (32,882) (35,377) Recognized net loss 2,853 3,481 1,430 Net other postretirement benefit income ($25,580) ($17,184) ($5,593) Other changes in plan assets and benefit obligations recognized as a regulatory asset and /or AOCI (before tax) Arising this period: Prior service credit for period ($3,168) ($128,837) $— Net (gain)/loss 6,210 41,031 (38,526) Amounts reclassified from regulatory asset and /or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 33,069 32,882 35,377 Amortization of net loss (2,853) (3,481) (1,430) Total $33,258 ($58,405) ($4,579) Total recognized as net periodic benefit (income)/cost, regulatory asset, and/or AOCI (before tax) $7,678 ($75,589) ($10,172)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Consolidated Balance Sheets of Entergy Corporation and its Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Thousands) Change in APBO Balance at January 1 $1,181,075 $1,252,903 Service cost 26,578 24,500 Interest cost 21,278 28,597 Plan amendments (3,168) (128,837) Plan participant contributions 22,023 37,176 Actuarial loss 20,955 80,162 Benefits paid (79,308) (113,786) Medicare Part D subsidy received 249 360 Balance at December 31 $1,189,682 $1,181,075 Change in Plan Assets Fair value of assets at January 1 $737,866 $686,262 Actual return on plan assets 57,965 80,011 Employer contributions 32,773 48,203 Plan participant contributions 22,023 37,176 Benefits paid (79,308) (113,786) Fair value of assets at December 31 $771,319 $737,866 Funded status ($418,363) ($443,209) Amounts recognized in the balance sheet Current liabilities ($42,000) ($38,963) Non-current liabilities (376,363) (404,246) Total funded status ($418,363) ($443,209) Amounts recognized as a regulatory asset Prior service credit ($37,693) ($45,501) Net gain (7,981) (8,565) ($45,674) ($54,066) Amounts recognized as AOCI (before tax) Prior service credit ($61,488) ($83,581) Net loss 27,138 24,365 ($34,350) ($59,216)
Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
Contributions To Defined Contribution Plans	The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $4,820 $6,678 $3,045 $1,140 $2,699 2020 $4,515 $6,518 $2,863 $1,115 $2,596 2019 $4,111 $5,641 $2,424 $882 $2,136
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—
Entergy Arkansas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $343 $307 $365 $30 $615 2020 $333 $148 $359 $31 $469 2019 $275 $159 $326 $20 $481
Schedule Of Projected Benefit Obligations	The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,875 $1,469 $3,708 $1,069 $7,462 2020 $3,197 $1,965 $3,852 $247 $8,475
Schedule Of Accumulated Benefit Obligations	The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,482 $1,445 $3,377 $738 $7,355 2020 $2,626 $1,802 $3,345 $240 $7,949
Schedule Of Amounts Recorded On The Balance Sheet	The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($248) ($186) ($190) ($31) ($3,080) Non-current liabilities (2,627) (1,283) (3,518) (1,039) (4,382) Total funded status ($2,875) ($1,469) ($3,708) ($1,070) ($7,462) Regulatory asset/(liability) $1,059 $233 $1,368 $251 ($706) Accumulated other comprehensive income (before taxes) $— $10 $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($218) ($193) ($181) ($17) ($633) Non-current liabilities (2,979) (1,772) (3,671) (230) (7,842) Total funded status ($3,197) ($1,965) ($3,852) ($247) ($8,475) Regulatory asset/(liability) $1,535 $424 $1,757 ($558) $147 Accumulated other comprehensive income (before taxes) $— $18 $— $— $—
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Reclassification Out of Accumulated Other Comprehensive Income, Amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2021: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $21,151 ($204) $20,947 Amortization of loss (84,661) (1,983) (2,194) (88,838) Settlement loss (12,001) — (4,378) (16,379) ($96,662) $19,168 ($6,776) ($84,270) Entergy Louisiana Amortization of prior service cost $— $4,920 $— $4,920 Amortization of loss (2,681) 364 (5) (2,322) Settlement loss (2,478) — (6) (2,484) ($5,159) $5,284 ($11) $114 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) as of December 31, 2020: Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service cost $— $21,000 ($231) $20,769 Amortization of loss (105,853) (1,006) (3,326) (110,185) Settlement loss (243) — — (243) ($106,096) $19,994 ($3,557) ($89,659) Entergy Louisiana Amortization of prior service cost $— $6,179 $— $6,179 Amortization of loss (2,001) 447 (3) (1,557) Settlement loss (243) — — (243) ($2,244) $6,626 ($3) $4,379
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
Contributions To Defined Contribution Plans	The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $4,820 $6,678 $3,045 $1,140 $2,699 2020 $4,515 $6,518 $2,863 $1,115 $2,596 2019 $4,111 $5,641 $2,424 $882 $2,136
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $343 $307 $365 $30 $615 2020 $333 $148 $359 $31 $469 2019 $275 $159 $326 $20 $481
Schedule Of Projected Benefit Obligations	The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,875 $1,469 $3,708 $1,069 $7,462 2020 $3,197 $1,965 $3,852 $247 $8,475
Schedule Of Accumulated Benefit Obligations	The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,482 $1,445 $3,377 $738 $7,355 2020 $2,626 $1,802 $3,345 $240 $7,949
Schedule Of Amounts Recorded On The Balance Sheet	The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($248) ($186) ($190) ($31) ($3,080) Non-current liabilities (2,627) (1,283) (3,518) (1,039) (4,382) Total funded status ($2,875) ($1,469) ($3,708) ($1,070) ($7,462) Regulatory asset/(liability) $1,059 $233 $1,368 $251 ($706) Accumulated other comprehensive income (before taxes) $— $10 $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($218) ($193) ($181) ($17) ($633) Non-current liabilities (2,979) (1,772) (3,671) (230) (7,842) Total funded status ($3,197) ($1,965) ($3,852) ($247) ($8,475) Regulatory asset/(liability) $1,535 $424 $1,757 ($558) $147 Accumulated other comprehensive income (before taxes) $— $18 $— $— $—
Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
Contributions To Defined Contribution Plans	The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $4,820 $6,678 $3,045 $1,140 $2,699 2020 $4,515 $6,518 $2,863 $1,115 $2,596 2019 $4,111 $5,641 $2,424 $882 $2,136
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—
Entergy Mississippi [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $343 $307 $365 $30 $615 2020 $333 $148 $359 $31 $469 2019 $275 $159 $326 $20 $481
Schedule Of Projected Benefit Obligations	The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,875 $1,469 $3,708 $1,069 $7,462 2020 $3,197 $1,965 $3,852 $247 $8,475
Schedule Of Accumulated Benefit Obligations	The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,482 $1,445 $3,377 $738 $7,355 2020 $2,626 $1,802 $3,345 $240 $7,949
Schedule Of Amounts Recorded On The Balance Sheet	The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($248) ($186) ($190) ($31) ($3,080) Non-current liabilities (2,627) (1,283) (3,518) (1,039) (4,382) Total funded status ($2,875) ($1,469) ($3,708) ($1,070) ($7,462) Regulatory asset/(liability) $1,059 $233 $1,368 $251 ($706) Accumulated other comprehensive income (before taxes) $— $10 $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($218) ($193) ($181) ($17) ($633) Non-current liabilities (2,979) (1,772) (3,671) (230) (7,842) Total funded status ($3,197) ($1,965) ($3,852) ($247) ($8,475) Regulatory asset/(liability) $1,535 $424 $1,757 ($558) $147 Accumulated other comprehensive income (before taxes) $— $18 $— $— $—
Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
Contributions To Defined Contribution Plans	The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $4,820 $6,678 $3,045 $1,140 $2,699 2020 $4,515 $6,518 $2,863 $1,115 $2,596 2019 $4,111 $5,641 $2,424 $882 $2,136
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—
Entergy New Orleans [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $343 $307 $365 $30 $615 2020 $333 $148 $359 $31 $469 2019 $275 $159 $326 $20 $481
Schedule Of Projected Benefit Obligations	The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,875 $1,469 $3,708 $1,069 $7,462 2020 $3,197 $1,965 $3,852 $247 $8,475
Schedule Of Accumulated Benefit Obligations	The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,482 $1,445 $3,377 $738 $7,355 2020 $2,626 $1,802 $3,345 $240 $7,949
Schedule Of Amounts Recorded On The Balance Sheet	The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($248) ($186) ($190) ($31) ($3,080) Non-current liabilities (2,627) (1,283) (3,518) (1,039) (4,382) Total funded status ($2,875) ($1,469) ($3,708) ($1,070) ($7,462) Regulatory asset/(liability) $1,059 $233 $1,368 $251 ($706) Accumulated other comprehensive income (before taxes) $— $10 $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($218) ($193) ($181) ($17) ($633) Non-current liabilities (2,979) (1,772) (3,671) (230) (7,842) Total funded status ($3,197) ($1,965) ($3,852) ($247) ($8,475) Regulatory asset/(liability) $1,535 $424 $1,757 ($558) $147 Accumulated other comprehensive income (before taxes) $— $18 $— $— $—
Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
Contributions To Defined Contribution Plans	The Registrant Subsidiaries’ 2021, 2020, and 2019 contributions to defined contribution plans for their employees were as follows: Year Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $4,820 $6,678 $3,045 $1,140 $2,699 2020 $4,515 $6,518 $2,863 $1,115 $2,596 2019 $4,111 $5,641 $2,424 $882 $2,136
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—
Entergy Texas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their employees for the non-qualified plans for 2021, 2020, and 2019, was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $343 $307 $365 $30 $615 2020 $333 $148 $359 $31 $469 2019 $275 $159 $326 $20 $481
Schedule Of Projected Benefit Obligations	The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,875 $1,469 $3,708 $1,069 $7,462 2020 $3,197 $1,965 $3,852 $247 $8,475
Schedule Of Accumulated Benefit Obligations	The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2021 and 2020 was as follows: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) 2021 $2,482 $1,445 $3,377 $738 $7,355 2020 $2,626 $1,802 $3,345 $240 $7,949
Schedule Of Amounts Recorded On The Balance Sheet	The following amounts were recorded on the balance sheet as of December 31, 2021 and 2020: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($248) ($186) ($190) ($31) ($3,080) Non-current liabilities (2,627) (1,283) (3,518) (1,039) (4,382) Total funded status ($2,875) ($1,469) ($3,708) ($1,070) ($7,462) Regulatory asset/(liability) $1,059 $233 $1,368 $251 ($706) Accumulated other comprehensive income (before taxes) $— $10 $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Current liabilities ($218) ($193) ($181) ($17) ($633) Non-current liabilities (2,979) (1,772) (3,671) (230) (7,842) Total funded status ($3,197) ($1,965) ($3,852) ($247) ($8,475) Regulatory asset/(liability) $1,535 $424 $1,757 ($558) $147 Accumulated other comprehensive income (before taxes) $— $18 $— $— $—
System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ total 2021, 2020, and 2019 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $28,632 $38,271 $9,070 $3,038 $6,921 $8,851 Interest cost on projected benefit obligation 35,683 39,740 10,446 4,392 8,381 9,087 Expected return on assets (78,368) (89,821) (22,407) (10,598) (21,158) (19,254) Recognized net loss 69,290 67,015 20,007 7,596 12,676 18,404 Settlement charges 37,682 61,945 16,710 5,431 11,797 12,260 Net pension cost $92,919 $117,150 $33,826 $9,859 $18,617 $29,348 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain ($96,066) ($89,534) ($29,675) ($16,159) ($18,217) ($27,617) Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,290) (67,015) (20,007) (7,596) (12,676) (18,404) Settlement charge (37,682) (61,945) (16,710) (5,431) (11,797) (12,260) Total ($203,038) ($218,494) ($66,392) ($29,186) ($42,690) ($58,281) Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) ($110,119) ($101,344) ($32,566) ($19,327) ($24,073) ($28,933) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $26,329 $35,158 $8,060 $2,654 $6,116 $7,883 Interest cost on projected benefit obligation 44,165 50,432 12,922 5,825 10,731 11,006 Expected return on assets (78,187) (89,691) (23,147) (10,509) (21,951) (18,757) Recognized net loss 68,338 66,640 18,983 8,018 13,173 17,104 Settlement charges 21,078 8,109 3,366 — 4,289 105 Net pension cost $81,723 $70,648 $20,184 $5,988 $12,358 $17,341 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $106,178 $90,064 $36,899 $8,148 $13,379 $35,403 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (69,713) (68,248) (19,393) (8,213) (13,564) (17,434) Settlement charge (21,078) (8,109) (3,366) — (4,289) (105) Total $15,387 $13,707 $14,140 ($65) ($4,474) $17,864 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $97,110 $84,355 $34,324 $5,923 $7,884 $35,205 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Net periodic pension cost: Service cost - benefits earned during the period $21,043 $29,137 $6,516 $2,274 $5,401 $6,199 Interest cost on projected benefit obligation 56,701 63,529 16,272 7,495 14,451 13,456 Expected return on assets (80,705) (90,607) (23,873) (10,785) (23,447) (18,710) Recognized net loss 47,361 46,571 12,416 6,117 9,335 11,400 Net pension cost $44,400 $48,630 $11,331 $5,101 $5,740 $12,345 Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net loss $118,898 $99,346 $41,088 $6,531 $10,869 $36,711 Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year: Amortization of net loss (47,361) (46,571) (12,416) (6,117) (9,335) (11,400) Total $71,537 $52,775 $28,672 $414 $1,534 $25,311 Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax) $115,937 $101,405 $40,003 $5,515 $7,274 $37,656
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Qualified pension obligations, plan assets, funded status, amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Service cost 28,632 38,271 9,070 3,038 6,921 8,851 Interest cost 35,683 39,740 10,446 4,392 8,381 9,087 Actuarial gain (41,227) (28,439) (14,831) (9,118) (3,971) (14,746) Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Balance at December 31 $1,579,346 $1,736,396 $448,858 $195,380 $371,802 $394,794 Change in Plan Assets Fair value of assets at $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Actual return on plan assets 133,207 150,917 37,251 17,639 35,405 32,125 Employer contributions 66,649 59,882 13,715 5,395 6,955 18,663 Benefits paid (a) (183,124) (240,447) (65,936) (23,219) (50,193) (49,546) Fair value of assets at December 31 $1,302,588 $1,446,658 $356,424 $172,366 $341,915 $312,060 Funded status ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($276,758) ($289,738) ($92,434) ($23,014) ($29,887) ($82,734) Amounts recognized as regulatory asset Net loss $612,963 $556,345 $173,511 $62,805 $113,790 $153,782 Amounts recognized as AOCI (before tax) Net loss $— $23,181 $— $— $— $— (a) Including settlement lump sum benefit payments of ($104.4) million at Entergy Arkansas, ($166.6) million at Entergy Louisiana, ($45.7) million at Entergy Mississippi, ($14.3) million at Entergy New Orleans, ($31.9) million at Entergy Texas, and ($33) million at System Energy. 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in Projected Benefit Obligation (PBO) Balance at January 1 $1,615,084 $1,784,474 $471,510 $206,962 $396,764 $393,607 Service cost 26,329 35,158 8,060 2,654 6,116 7,883 Interest cost 44,165 50,432 12,922 5,825 10,731 11,006 Actuarial loss 196,755 196,032 62,564 20,535 37,579 57,574 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Balance at December 31 $1,739,382 $1,927,271 $510,109 $220,287 $410,664 $441,148 Change in Plan Assets Fair value of assets at January 1 $1,200,035 $1,364,030 $354,928 $160,777 $339,126 $282,668 Actual return on plan assets 168,764 195,658 48,812 22,896 46,151 40,927 Employer contributions 60,008 55,443 12,601 4,567 4,997 16,145 Benefits paid (a) (142,951) (138,825) (44,947) (15,689) (40,526) (28,922) Fair value of assets at December 31 $1,285,856 $1,476,306 $371,394 $172,551 $349,748 $310,818 Funded status ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized in the balance sheet (funded status) Non-current liabilities ($453,526) ($450,965) ($138,715) ($47,736) ($60,916) ($130,330) Amounts recognized as regulatory asset Net loss $816,002 $766,099 $239,904 $91,991 $156,480 $212,062 Amounts recognized as AOCI (before tax) Net loss $— $31,921 $— $— $— $—
Schedule Of Accumulated Benefit Obligations	The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees as of December 31, 2021 and 2020 was as follows: December 31, 2021 2020 (In Thousands) Entergy Arkansas $1,463,966 $1,617,858 Entergy Louisiana $1,574,273 $1,753,980 Entergy Mississippi $407,851 $466,497 Entergy New Orleans $178,010 $201,159 Entergy Texas $342,441 $379,050 System Energy $366,920 $410,296
Estimated Future Benefit Payments	Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows: Estimated Future Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $107,542 $120,365 $33,459 $13,992 $31,134 $26,953 2023 $104,328 $118,289 $33,055 $13,677 $30,381 $25,985 2024 $104,606 $117,416 $32,711 $13,333 $28,661 $26,155 2025 $102,411 $116,610 $31,838 $13,146 $26,807 $25,203 2026 $101,144 $114,232 $31,708 $12,875 $26,983 $24,939 2027 - 2031 $487,637 $534,665 $143,052 $58,299 $114,747 $123,220 Estimated Future Non-Qualified Pension Benefits Payments Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Thousands) Year(s) 2022 $248 $186 $190 $31 $3,080 2023 $383 $172 $422 $82 $441 2024 $324 $159 $504 $104 $420 2025 $689 $146 $486 $135 $398 2026 $143 $133 $412 $128 $428 2027 - 2031 $878 $503 $1,927 $782 $1,677 Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy) Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $14,228 $15,845 $3,488 $2,449 $5,061 $2,828 2023 $13,652 $15,766 $3,550 $2,378 $4,998 $2,774 2024 $13,392 $15,404 $3,597 $2,288 $4,824 $2,668 2025 $13,021 $15,182 $3,657 $2,200 $4,686 $2,617 2026 $12,717 $14,868 $3,645 $2,096 $4,458 $2,511 2027 - 2031 $61,153 $70,094 $18,095 $9,058 $20,932 $12,474 Estimated Future Medicare Part D Subsidy Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Year(s) 2022 $35 $6 $14 $— $— $1 2023 $3 $5 $15 $— $— $1 2024 $4 $7 $16 $— $— $1 2025 $4 $8 $17 $— $— $— 2026 $5 $7 $18 $1 $— $1 2027 - 2031 $27 $51 $104 $— $— $4
Expected Employer Contributions	The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their employees in 2022: Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Pension Contributions $40,840 $22,917 $12,852 $922 $1,924 $12,760 Other Postretirement Contributions $517 $15,845 $130 $175 $66 $22
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Total 2021, 2020, and 2019 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy Other postretirement costs: Service cost - benefits earned during the period $4,135 $6,174 $1,448 $437 $1,384 $1,340 Interest cost on APBO 3,726 4,520 1,110 521 1,269 878 Expected return on assets (18,020) — (5,536) (5,750) (10,192) (3,156) Amortization of prior service credit (1,121) (4,920) (1,775) (916) (3,742) (436) Recognized net (gain)/ loss 196 (364) 76 (712) 398 61 Net other postretirement benefit (income)/cost ($11,084) $5,410 ($4,677) ($6,420) ($10,883) ($1,313) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period ($85) $357 $— $— ($3,776) $69 Net (gain)/loss $9,956 ($2,367) ($2,823) ($3,330) $939 $210 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,121 4,920 1,775 916 3,742 436 Amortization of net (gain)/loss (196) 364 (76) 712 (398) (61) Total $10,796 $3,274 ($1,124) ($1,702) $507 $654 Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($288) $8,684 ($5,801) ($8,122) ($10,376) ($659) 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $3,626 $5,993 $1,468 $445 $1,219 $1,254 Interest cost on APBO 4,712 6,216 1,536 784 2,008 1,130 Expected return on assets (17,104) — (5,167) (5,382) (9,643) (2,958) Amortization of prior service credit (1,849) (6,179) (1,652) (763) (3,364) (1,065) Recognized net (gain)/loss 540 (447) 171 (13) 907 121 Net other postretirement benefit (income)/cost ($10,075) $5,583 ($3,644) ($4,929) ($8,873) ($1,518) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Prior service cost/(credit) for the period $12,320 ($23,508) ($4,428) ($5,493) ($22,441) ($1,963) Net (gain)/loss $2,245 $8,744 ($4,456) ($5,351) ($3,266) $58 Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 1,849 6,179 1,652 763 3,364 1,065 Amortization of net (gain)/ loss (540) 447 (171) 13 (907) (121) Total $15,874 ($8,138) ($7,403) ($10,068) ($23,250) ($961) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) $5,799 ($2,555) ($11,047) ($14,997) ($32,123) ($2,479) 2019 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Other postretirement costs: Service cost - benefits earned during the period $2,363 $4,639 $1,046 $367 $943 $973 Interest cost on APBO 7,226 10,664 2,681 1,581 3,415 1,902 Expected return on assets (15,962) — (4,794) (4,947) (9,103) (2,788) Amortization of prior service credit (4,950) (7,349) (1,756) (682) (2,243) (1,450) Recognized net (gain)/loss 576 (695) 723 231 485 354 Net other postretirement benefit (income)/cost ($10,747) $7,259 ($2,100) ($3,450) ($6,503) ($1,009) Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax) Arising this period: Net gain (26,707) (2,220) (11,950) (10,967) (6,406) (5,539) Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year: Amortization of prior service credit 4,950 7,349 1,756 682 2,243 1,450 Amortization of net (gain)/loss (576) 695 (723) (231) (485) (354) Total ($22,333) $5,824 ($10,917) ($10,516) ($4,648) ($4,443) Total recognized as net periodic other postretirement (income)/cost, regulatory asset, and/or AOCI (before tax) ($33,080) $13,083 ($13,017) ($13,966) ($11,151) ($5,452)
Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet	Other postretirement benefit obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2021 and 2020 are as follows: 2021 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Service cost 4,135 6,174 1,448 437 1,384 1,340 Interest cost 3,726 4,520 1,110 521 1,269 878 Plan amendments (85) 357 — — (3,776) 69 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Actuarial (gain)/loss 14,323 (2,367) (1,335) 988 4,270 1,289 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Medicare Part D subsidy received 32 50 6 4 13 14 Balance at December 31 $221,183 $253,031 $61,001 $31,866 $71,961 $47,875 Change in Plan Assets Fair value of assets at January 1 $304,192 $— $93,475 $102,734 $174,096 $52,619 Actual return on plan assets 22,387 — 7,024 10,068 13,523 4,235 Employer contributions (767) 11,274 (393) 126 98 1,212 Plan participant contributions 5,637 5,186 1,386 403 1,491 1,353 Benefits paid (15,954) (16,460) (3,604) (2,194) (6,923) (4,769) Fair value of assets at December 31 $315,495 $— $97,888 $111,137 $182,285 $54,650 Funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in the balance sheet Current liabilities $— ($15,839) $— $— $— $— Non-current liabilities 94,312 (237,192) 36,887 79,271 110,324 6,775 Total funded status $94,312 ($253,031) $36,887 $79,271 $110,324 $6,775 Amounts recognized in regulatory asset Prior service cost/(credit) $8,691 $— ($4,109) ($3,814) ($20,532) ($1,249) Net (gain)/loss (6,797) — (4,254) (16,003) 2,571 2,967 $1,894 $— ($8,363) ($19,817) ($17,961) $1,718 Amounts recognized in AOCI (before tax) Prior service credit $— ($16,967) $— $— $— $— Net gain — (17,551) — — — — $— ($34,518) $— $— $— $— 2020 Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Thousands) Change in APBO Balance at January 1 $185,744 $274,175 $65,979 $38,460 $94,742 $47,348 Service cost 3,626 5,993 1,468 445 1,219 1,254 Interest cost 4,712 6,216 1,536 784 2,008 1,130 Plan amendments 12,320 (23,508) (4,428) (5,493) (22,441) (1,963) Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Actuarial (gain)/loss 18,257 8,744 684 (91) 5,952 3,025 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Medicare Part D subsidy received 59 77 11 9 18 26 Balance at December 31 $209,369 $255,571 $61,990 $31,707 $74,233 $47,701 Change in Plan Assets Fair value of assets at January 1 $284,224 $— $86,085 $93,858 $161,810 $48,471 Actual return on plan assets 33,116 — 10,307 10,642 18,861 5,925 Employer contributions 2,201 16,126 343 641 690 1,342 Plan participant contributions 7,792 8,269 2,122 1,123 2,456 1,732 Benefits paid (23,141) (24,395) (5,382) (3,530) (9,721) (4,851) Fair value of assets at December 31 $304,192 $— $93,475 $102,734 $174,096 $52,619 Funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in the balance sheet Current liabilities $— ($15,580) $— $— $— $— Non-current liabilities 94,823 (239,991) 31,485 71,027 99,863 4,918 Total funded status $94,823 ($255,571) $31,485 $71,027 $99,863 $4,918 Amounts recognized in regulatory asset Prior service cost/(credit) $7,655 $— ($5,884) ($4,730) ($20,498) ($1,754) Net (gain)/loss (16,557) — (1,355) (13,385) 2,030 2,818 ($8,902) $— ($7,239) ($18,115) ($18,468) $1,064 Amounts recognized in AOCI (before tax) Prior service credit $— ($22,244) $— $— $— $— Net gain — (15,548) — — — — $— ($37,792) $— $— $— $—

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule Of Financial Information For Stock Options	The following table includes financial information for stock options for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $4.2 $3.9 $3.8 Tax benefit recognized in Entergy’s consolidated net income $1.1 $1.0 $1.0 Compensation cost capitalized as part of fixed assets and inventory $1.5 $1.5 $1.4
Schedule of Weighted Average Assumptions	The stock option weighted-average assumptions used in determining the fair values are as follows: 2021 2020 2019 Stock price volatility 23.93% 17.16% 17.23% Expected term in years 6.93 7.04 7.32 Risk-free interest rate 0.74% 1.49% 2.50% Dividend yield 4.00% 4.00% 4.50% Dividend payment per share $3.86 $3.74 $3.66
Schedule of Stock Option Activity	A summary of stock option activity for the year ended December 31, 2021 and changes during the year are presented below: Number of Options Weighted- Aggregate Intrinsic Value Weighted- Options outstanding as of January 1, 2021 2,399,379 $89.63 Options granted 508,704 $95.87 Options exercised (72,138) $80.54 Options forfeited/expired (16,301) $117.89 Options outstanding as of December 31, 2021 2,819,644 $90.82 $71,110,949 6.34 years Options exercisable as of December 31, 2021 1,788,702 $81.91 $58,164,228 5.16 years Weighted-average grant-date fair value of options granted during 2021 $12.27
Schedule of Stock Options Outstanding	The following table summarizes information about stock options outstanding as of December 31, 2021: Options Outstanding Options Exercisable Range of Exercise Price As of December 31, 2021 Weighted-Average Remaining Contractual Life-Yrs. Weighted Average Exercise Price Number Exercisable as of December 31, 2021 Weighted Average Exercise Price $51 - $64.99 240,200 1.72 $63.69 240,200 $63.69 $65 - $78.99 915,839 5.19 $73.80 915,839 $73.80 $79 - $91.99 653,585 6.21 $89.35 465,577 $89.41 $92 - $131.72 1,010,020 8.58 $113.66 167,086 $131.72 $51 - $131.72 2,819,644 6.34 $90.82 1,788,702 $81.91
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule Of Financial Information For Stock Options	The following table includes financial information for restricted stock for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $24.7 $23.1 $20.2 Tax benefit recognized in Entergy’s consolidated net income $6.3 $5.9 $5.1 Compensation cost capitalized as part of fixed assets and inventory $9.3 $8.5 $7.1
Schedule of Stock Options Outstanding	The following table includes information about the restricted stock awards outstanding as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 648,498 $107.89 Granted 419,095 $96.45 Vested (323,698) $99.28 Forfeited (58,540) $108.57 Outstanding shares at December 31, 2021 685,355 $104.91
Long-Term Incentive Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule Of Financial Information For Stock Options	The following table includes financial information for the long-term performance units for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $14.5 $12.6 $11.1 Tax benefit recognized in Entergy’s consolidated net income $3.7 $3.2 $2.8 Compensation cost capitalized as part of fixed assets and inventory $5.8 $4.9 $4.0
Schedule of Stock Options Outstanding	The following table includes information about the long-term performance units outstanding at the target level as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 475,765 $110.82 Granted 303,092 $104.02 Vested (235,983) $82.42 Forfeited (21,038) $122.87 Outstanding shares at December 31, 2021 521,836 $119.23
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule Of Financial Information For Stock Options	The following table includes financial information for restricted stock unit awards for each of the years presented: 2021 2020 2019 (In Millions) Compensation expense included in Entergy’s consolidated net income $1.9 $2.0 $2.2 Tax benefit recognized in Entergy’s consolidated net income $0.5 $0.5 $0.6 Compensation cost capitalized as part of fixed assets and inventory $0.7 $0.9 $0.9
Schedule of Stock Options Outstanding	The following table includes information about the restricted stock unit awards outstanding as of December 31, 2021: Shares Weighted-Average Grant Date Fair Value Per Share Outstanding shares at January 1, 2021 86,175 $92.92 Granted 39,478 $105.06 Vested (37,005) $90.89 Outstanding shares at December 31, 2021 88,648 $99.18

Business Segment Information Bu

Business Segment Information Business Segment Information (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment	Entergy’s segment financial information was as follows: 2021 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $11,044,674 $698,164 $87 ($29) $11,742,896 Asset write-offs, impairments, and related charges $— $263,625 $— $— $263,625 Depreciation, amortization, & decommissioning $1,823,389 $164,602 $2,706 $— $1,990,697 Interest and investment income $442,817 $118,597 $10,932 ($141,880) $430,466 Interest expense $692,004 $13,334 $143,614 ($14,258) $834,694 Income taxes $264,209 ($25,381) ($47,454) $— $191,374 Consolidated net income (loss) $1,488,487 ($120,689) ($121,457) ($127,622) $1,118,719 Total assets $59,733,625 $1,242,675 $561,168 ($2,083,226) $59,454,242 Cash paid for long-lived asset additions $6,409,855 $12,100 $157 $— $6,422,112 2020 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,170,714 $942,869 $78 ($25) $10,113,636 Asset write-offs, impairments, and related charges $— $26,623 $— $— $26,623 Depreciation, amortization, & decommissioning $1,685,138 $306,974 $2,835 $— $1,994,947 Interest and investment income $299,004 $234,194 $19,563 ($159,943) $392,818 Interest expense $648,851 $22,432 $146,730 ($32,350) $785,663 Income taxes ($282,311) $104,937 $55,868 $— ($121,506) Consolidated net income (loss) $1,816,354 ($62,763) ($219,344) ($127,594) $1,406,653 Total assets $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 Cash paid for long-lived asset additions $5,102,322 $54,455 $84 $— $5,156,861 2019 Utility Entergy Wholesale Commodities All Other Eliminations Consolidated (In Thousands) Operating revenues $9,583,985 $1,294,719 $21 ($52) $10,878,673 Asset write-offs, impairments, and related charges $— $290,027 $— $— $290,027 Depreciation, amortization, & decommissioning $1,493,167 $384,707 $2,944 $— $1,880,818 Interest and investment income $289,570 $414,636 $26,295 ($182,589) $547,912 Interest expense $589,395 $29,450 $178,575 ($54,995) $742,425 Income taxes $19,634 ($161,295) ($28,164) $— ($169,825) Consolidated net income (loss) $1,425,643 $148,870 ($188,675) ($127,594) $1,258,244 Total assets $49,557,664 $4,154,961 $514,020 ($2,502,733) $51,723,912 Cash paid for long-lived asset additions $4,527,045 $104,300 $160 $— $4,631,505
Restructuring and Related Costs	Total restructuring charges in 2021, 2020, and 2019 were comprised of the following: Employee retention and severance expenses and other benefits-related costs Contracted economic development costs Total (In Millions) Balance as of December 31, 2018 $179 $14 $193 Restructuring costs accrued 91 — 91 Cash paid out 141 — 141 Balance as of December 31, 2019 $129 $14 $143 Restructuring costs accrued 71 — 71 Cash paid out 55 — 55 Balance as of December 31, 2020 $145 $14 $159 Restructuring costs accrued 12 1 13 Cash paid out 120 15 135 Balance as of December 31, 2021 $37 $— $37

Risk Management And Fair Valu_2

Risk Management And Fair Values (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2021 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) Business (In Millions) Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $6 $— $6 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $5 $— $5 Utility Financial transmission rights Prepayments and other $4 $— $4 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $7 $— $7 Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 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) Business (In Millions) Derivatives designated as hedging instruments Electricity swaps and options Prepayments and other (current portion) $39 ($1) $38 Entergy Wholesale Commodities Liabilities: Electricity swaps and options Other current liabilities (current portion) $1 ($1) $— Entergy Wholesale Commodities Derivatives not designated as hedging instruments Assets: Natural gas swaps and options Prepayments and other (current portion) $1 $— $1 Utility Natural gas swaps and options Other deferred debits and other assets (non-current portion) $1 $— $1 Utility Financial transmission rights Prepayments and other $9 $— $9 Utility and Entergy Wholesale Commodities Liabilities: Natural gas swaps and options Other current liabilities (current portion) $6 $— $6 Utility Natural gas swaps and options Other non-current liabilities (non-current portion) $1 $— $1 Utility (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 Sheet (d) Excludes cash collateral in the amount of $8 million posted as of December 31, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $1 million posted and $39 million held as of December 31, 2020.
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Amount of gain (loss) recognized in other comprehensive income Income Statement location Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a) (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive business operating revenues $40 2020 Electricity swaps and options $77 Competitive business operating revenues $148 2019 Electricity swaps and options $232 Competitive business operating revenues $97 (a) Before taxes of $8 million, $31 million, and $20 million, for the years ended December 31, 2021, 2020, and 2019, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement location Amount of gain (loss) recorded in the income statement (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $32 Financial transmission rights Purchased power expense (b) $179 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps and option Fuel, fuel-related expenses, and gas purchased for resale (a) ($12) Financial transmission rights Purchased power expense (b) $92 Electricity swaps and options (c) Competitive business operating revenues $1 2019 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($13) Financial transmission rights Purchased power expense (b) $94 Electricity swaps and options (c) Competitive business operating revenues $12 (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2021 and December 31, 2020. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels. 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $398 $— $— $398 Decommissioning trust funds (a): Equity securities 132 — — 132 Debt securities (b) 770 1,407 — 2,177 Common trusts (c) 3,205 Securitization recovery trust account 29 — — 29 Escrow accounts 49 — — 49 Gas hedge contracts 6 5 — 11 Financial transmission rights — — 4 4 $1,384 $1,412 $4 $6,005 Liabilities: Gas hedge contracts $7 $— $— $7 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $1,630 $— $— $1,630 Decommissioning trust funds (a): Equity securities 1,533 — — 1,533 Debt securities 919 1,698 — 2,617 Common trusts (c) 3,103 Power contracts — — 38 38 Securitization recovery trust account 42 — — 42 Escrow accounts 148 — — 148 Gas hedge contracts 1 1 — 2 Financial transmission rights — — 9 9 $4,273 $1,699 $47 $9,122 Liabilities: Gas hedge contracts $6 $1 $— $7 (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 for additional information on the investment portfolios. (b) The decommissioning trust funds fair value presented herein does not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.4 million as of December 31, 2021 and $0.1 million as of December 31, 2020 on debt securities. See Note 16 to the financial statements for additional information on the allowance for expected credit losses. (c) 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.
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2021, 2020, and 2019: 2021 2020 2019 Power Contracts Financial transmission rights Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, $38 $9 $118 $10 ($31) $15 Total gains (losses) for the period (a) Included in earnings (2) — 1 1 12 — Included in other comprehensive income 2 — 77 — 232 — Included as a regulatory liability/asset — 162 — 67 — 54 Issuances of financial transmission rights — 12 — 23 — 35 Settlements (38) (179) (158) (92) (95) (94) Balance as of December 31, $— $4 $38 $9 $118 $10 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($0.3) million and ($9.2) million for the years ended December 31, 2020 and 2019, respectively.
Entergy Arkansas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 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
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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.
Assets and liabilities at fair value on a recurring basis	Entergy Arkansas 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $4.8 $— $— $4.8 Decommissioning trust funds (a): Equity securities 16.7 — — 16.7 Debt securities 119.5 406.8 — 526.3 Common trusts (b) 895.4 Financial transmission rights — — 2.3 2.3 $141.0 $406.8 $2.3 $1,445.5 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $168.0 $— $— $168.0 Decommissioning trust funds (a): Equity securities 1.3 — — 1.3 Debt securities 98.2 349.7 — 447.9 Common trusts (b) 824.7 Financial transmission rights — — 2.7 2.7 $267.5 $349.7 $2.7 $1,444.6
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2021 $2.7 $4.2 $0.6 $0.1 $1.6 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 39.4 23.9 9.3 3.9 82.4 Settlements (42.6) (31.6) (11.3) (4.3) (85.9) Balance as of December 31, 2021 $2.3 $0.6 $0.3 $0.1 $0.8 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2020 $3.3 $4.5 $0.8 $0.3 $0.9 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 19.6 6.1 1.4 1.3 38.7 Settlements (26.7) (19.6) (3.0) (1.4) (40.4) Balance as of December 31, 2020 $2.7 $4.2 $0.6 $0.1 $1.6
Entergy Louisiana [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 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
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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.
Assets and liabilities at fair value on a recurring basis	Entergy Louisiana 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $18.4 $— $— $18.4 Decommissioning trust funds (a): Equity securities 20.2 — — 20.2 Debt securities 262.6 531.6 — 794.2 Common trusts (b) 1,300.1 Gas hedge contracts 5.7 5.3 — 11.0 Financial transmission rights — — 0.6 0.6 $306.9 $536.9 $0.6 $2,144.5 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $726.7 $— $— $726.7 Decommissioning trust funds (a): Equity securities 8.7 — — 8.7 Debt securities 172.4 459.8 — 632.2 Common trusts (b) 1,153.1 Securitization recovery trust account 2.7 — — 2.7 Gas hedge contracts 0.8 0.5 — 1.3 Financial transmission rights — — 4.2 4.2 $911.3 $460.3 $4.2 $2,528.9 Liabilities: Gas hedge contracts $0.3 $1.3 $— $1.6
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2021 $2.7 $4.2 $0.6 $0.1 $1.6 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 39.4 23.9 9.3 3.9 82.4 Settlements (42.6) (31.6) (11.3) (4.3) (85.9) Balance as of December 31, 2021 $2.3 $0.6 $0.3 $0.1 $0.8 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2020 $3.3 $4.5 $0.8 $0.3 $0.9 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 19.6 6.1 1.4 1.3 38.7 Settlements (26.7) (19.6) (3.0) (1.4) (40.4) Balance as of December 31, 2020 $2.7 $4.2 $0.6 $0.1 $1.6
Entergy Mississippi [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 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
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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.
Assets and liabilities at fair value on a recurring basis	Entergy Mississippi 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $47.6 $— $— $47.6 Escrow accounts 48.9 — — 48.9 Financial transmission rights — — 0.3 0.3 $96.5 $— $0.3 $96.8 Liabilities: Gas hedge contracts $6.7 $— $— $6.7 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Escrow accounts $64.6 $— $— $64.6 Financial transmission rights — — 0.6 0.6 $64.6 $— $0.6 $65.2 Liabilities: Gas hedge contracts $5.0 $— $— $5.0
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2021 $2.7 $4.2 $0.6 $0.1 $1.6 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 39.4 23.9 9.3 3.9 82.4 Settlements (42.6) (31.6) (11.3) (4.3) (85.9) Balance as of December 31, 2021 $2.3 $0.6 $0.3 $0.1 $0.8 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2020 $3.3 $4.5 $0.8 $0.3 $0.9 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 19.6 6.1 1.4 1.3 38.7 Settlements (26.7) (19.6) (3.0) (1.4) (40.4) Balance as of December 31, 2020 $2.7 $4.2 $0.6 $0.1 $1.6
Entergy New Orleans [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 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
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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.
Assets and liabilities at fair value on a recurring basis	Entergy New Orleans 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $42.8 $— $— $42.8 Securitization recovery trust account 2.0 — — 2.0 Financial transmission rights — — 0.1 0.1 $44.8 $— $0.1 $44.9 Liabilities: Gas hedge contracts $0.5 $— $— $0.5 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Securitization recovery trust account $3.4 $— $— $3.4 Escrow accounts 83.0 — — 83.0 Financial transmission rights — — 0.1 0.1 $86.4 $— $0.1 $86.5 Liabilities: Gas hedge contracts $0.3 $— $— $0.3
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2021 $2.7 $4.2 $0.6 $0.1 $1.6 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 39.4 23.9 9.3 3.9 82.4 Settlements (42.6) (31.6) (11.3) (4.3) (85.9) Balance as of December 31, 2021 $2.3 $0.6 $0.3 $0.1 $0.8 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2020 $3.3 $4.5 $0.8 $0.3 $0.9 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 19.6 6.1 1.4 1.3 38.7 Settlements (26.7) (19.6) (3.0) (1.4) (40.4) Balance as of December 31, 2020 $2.7 $4.2 $0.6 $0.1 $1.6
Entergy Texas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2021 and 2020 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 2021 Assets: Natural gas swaps and options Prepayments and other $5.7 $— $5.7 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $5.3 $— $5.3 Entergy Louisiana Financial transmission rights Prepayments and other $2.3 $— $2.3 Entergy Arkansas Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Louisiana Financial transmission rights Prepayments and other $0.3 $— $0.3 Entergy Mississippi Financial transmission rights Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $0.8 $— $0.8 Entergy Texas Liabilities: Natural gas swaps Other current liabilities $6.7 $— $6.7 Entergy Mississippi Natural gas swaps Other current liabilities $0.5 $— $0.5 Entergy New Orleans Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant 2020 Assets: Natural gas swaps and options Prepayments and other $0.8 $— $0.8 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets $0.5 $— $0.5 Entergy Louisiana Financial transmission rights Prepayments and other $2.9 ($0.2) $2.7 Entergy Arkansas Financial transmission rights Prepayments and other $4.3 ($0.1) $4.2 Entergy Louisiana Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy Mississippi Financial transmission rights Prepayments and other $0.2 ($0.1) $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $1.6 $— $1.6 Entergy Texas Liabilities: Natural gas swaps and options Other current liabilities $0.3 $— $0.3 Entergy Louisiana Natural gas swaps and options Other non-current liabilities $1.3 $— $1.3 Entergy Louisiana Natural gas swaps Other current liabilities $5.0 $— $5.0 Entergy Mississippi Natural gas swaps Other current liabilities $0.3 $— $0.3 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
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the years ended December 31, 2021, 2020, and 2019 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $12.6 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $19.8 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.1) (a) Entergy New Orleans Financial transmission rights Purchased power $42.6 (b) Entergy Arkansas Financial transmission rights Purchased power $31.6 (b) Entergy Louisiana Financial transmission rights Purchased power $11.3 (b) Entergy Mississippi Financial transmission rights Purchased power $4.3 (b) Entergy New Orleans Financial transmission rights Purchased power $85.9 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($11.1) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.8) (a) Entergy New Orleans Financial transmission rights Purchased power $26.7 (b) Entergy Arkansas Financial transmission rights Purchased power $19.6 (b) Entergy Louisiana Financial transmission rights Purchased power $3.0 (b) Entergy Mississippi Financial transmission rights Purchased power $1.4 (b) Entergy New Orleans Financial transmission rights Purchased power $40.4 (b) Entergy Texas 2019 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($5.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Financial transmission rights Purchased power $22.3 (b) Entergy Arkansas Financial transmission rights Purchased power $46.7 (b) Entergy Louisiana Financial transmission rights Purchased power $6.8 (b) Entergy Mississippi Financial transmission rights Purchased power $2.7 (b) Entergy New Orleans Financial transmission rights Purchased power $15.7 (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.
Assets and liabilities at fair value on a recurring basis	Entergy Texas 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets : Securitization recovery trust account $26.6 $— $— $26.6 Financial transmission rights — — 0.8 0.8 $26.6 $— $0.8 $27.4 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets : Temporary cash investments $248.6 $— $— $248.6 Securitization recovery trust account 36.2 — — 36.2 Financial transmission rights — — 1.6 1.6 $284.8 $— $1.6 $286.4
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2021. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2021 $2.7 $4.2 $0.6 $0.1 $1.6 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 39.4 23.9 9.3 3.9 82.4 Settlements (42.6) (31.6) (11.3) (4.3) (85.9) Balance as of December 31, 2021 $2.3 $0.6 $0.3 $0.1 $0.8 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2020. Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas (In Millions) Balance as of January 1, 2020 $3.3 $4.5 $0.8 $0.3 $0.9 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 19.6 6.1 1.4 1.3 38.7 Settlements (26.7) (19.6) (3.0) (1.4) (40.4) Balance as of December 31, 2020 $2.7 $4.2 $0.6 $0.1 $1.6
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $89.1 $— $— $89.1 Decommissioning trust funds (a): Equity securities 12.9 — — 12.9 Debt securities 273.0 251.5 — 524.5 Common trusts (b) 847.9 $375.0 $251.5 $— $1,474.4 2020 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $216.4 $— $— $216.4 Decommissioning trust funds (a): Equity securities 3.8 — — 3.8 Debt securities 177.3 250.4 — 427.7 Common trusts (b) 784.4 $397.5 $250.4 $— $1,432.3

Decommissioning Trust Funds (Ta

Decommissioning Trust Funds (Tables)	12 Months Ended
	Dec. 31, 2021
Securities Held	The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $2,177 $65 $12 2020 Debt Securities $2,617 $197 $3
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 473 672 5 years - 10 years 655 852 10 years - 15 years 389 377 15 years - 20 years 130 144 20 years+ 530 576 Total $2,177 $2,617
Debt Securities, Available-for-sale, Unrealized Loss Position, Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $770 $8 $187 $3 More than 12 months 99 4 2 — Total $869 $12 $189 $3
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $526.3 $11.4 $4.7 2020 Debt Securities $447.9 $27.7 $0.3
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 91.7 113.1 5 years - 10 years 217.4 189.8 10 years - 15 years 146.0 81.4 15 years - 20 years 35.7 28.5 20 years+ 35.5 35.1 Total $526.3 $447.9
Debt Securities, Available-for-sale, Unrealized Loss Position, Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $183.8 $2.9 $29.9 $0.3 More than 12 months 39.5 1.8 — — Total $223.3 $4.7 $29.9 $0.3
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $794.2 $31.3 $3.3 2020 Debt Securities $632.2 $51.3 $0.5
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 157.8 117.0 5 years - 10 years 173.0 159.4 10 years - 15 years 123.0 101.2 15 years - 20 years 80.2 66.9 20 years+ 260.2 187.7 Total $794.2 $632.2
Debt Securities, Available-for-sale, Unrealized Loss Position, Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $206.9 $1.4 $36.4 $0.5 More than 12 months 42.9 1.9 0.8 — Total $249.8 $3.3 $37.2 $0.5
System Energy [Member]
Securities Held	The available-for-sale securities held as of December 31, 2021 and 2020 are summarized as follows: Fair Value Total Unrealized Gains Total Unrealized Losses (In Millions) 2021 Debt Securities $524.5 $11.8 $2.9 2020 Debt Securities $427.7 $30.0 $0.8
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of December 31, 2021 and 2020 are as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 156.8 134.7 5 years - 10 years 161.8 141.5 10 years - 15 years 58.6 31.5 15 years - 20 years 1.9 5.3 20 years+ 145.4 115.8 Total $524.5 $427.7
Debt Securities, Available-for-sale, Unrealized Loss Position, Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of December 31, 2021 and 2020: December 31, 2021 December 31, 2020 Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses (In Millions) Less than 12 months $276.6 $2.3 $28.9 $0.8 More than 12 months 11.3 0.6 — — Total $287.9 $2.9 $28.9 $0.8

Transactions With Affiliates (T

Transactions With Affiliates (Tables)	12 Months Ended
	Dec. 31, 2021
Entergy Arkansas [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0
Entergy Louisiana [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0
Entergy Mississippi [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0
Entergy New Orleans [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0
Entergy Texas [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0
System Energy [Member]
Schedule Of Affiliate Transactions	The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $109.8 $289.9 $1.4 $— $64.3 $545.6 2020 $105.2 $280.5 $1.2 $— $40.4 $520.7 2019 $117.5 $277.8 $1.4 $— $51.6 $584.1 Intercompany Operating Expenses Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $559.7 $755.2 $299.8 $287.8 $275.0 $190.8 2020 $515.5 $661.5 $283.3 $266.0 $260.3 $177.4 2019 $534.0 $665.4 $306.7 $292.1 $255.0 $156.2 Intercompany Interest and Investment Income Entergy Arkansas Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy (In Millions) 2021 $— $127.6 $— $— $— $— 2020 $— $127.7 $0.1 $— $— $0.2 2019 $0.4 $128.5 $0.4 $— $0.4 $1.0

Revenue Recognition Revenue R_2

Revenue Recognition Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2021
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the years ended December 31, 2021, 2020 and 2019 are as follows: 2021 2020 2019 (In Thousands) Utility: Residential $3,981,846 $3,550,317 $3,531,500 Commercial 2,610,207 2,292,740 2,475,586 Industrial 2,942,370 2,331,170 2,541,287 Governmental 245,685 212,131 228,470 Total billed retail 9,780,108 8,386,358 8,776,843 Sales for resale (a) 601,895 295,810 285,722 Other electric revenues (b) 375,312 348,102 343,143 Revenues from contracts with customers 10,757,315 9,030,270 9,405,708 Other revenues (c) 116,680 16,373 24,270 Total electric revenues 10,873,995 9,046,643 9,429,978 Natural gas 170,610 124,008 153,954 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 672,493 771,360 1,164,552 Other revenues (c) 25,798 171,625 130,189 Total competitive businesses revenues 698,291 942,985 1,294,741 Total operating revenues $11,742,896 $10,113,636 $10,878,673
Allowance For Doubtful Accounts [Table Text Block]	The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125
Allowance For Doubtful Accounts [Table Text Block]	The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125
Allowance For Doubtful Accounts [Table Text Block]	The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125 The Utility operating companies’ total revenues for the year ended December 31, 2019 were as follows: 2019 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $795,269 $1,270,478 $562,219 $245,081 $658,453 Commercial 538,850 947,412 444,173 202,138 343,013 Industrial 520,958 1,450,966 164,491 31,824 373,048 Governmental 20,795 71,046 44,300 70,865 21,464 Total billed retail 1,875,872 3,739,902 1,215,183 549,908 1,395,978 Sales for resale (a) 257,864 333,395 39,295 38,626 59,074 Other electric revenues (b) 112,618 135,783 58,269 9,842 32,424 Revenues from contracts with customers 2,246,354 4,209,080 1,312,747 598,376 1,487,476 Other revenues (c) 13,240 13,947 10,296 (3,959) 1,479 Total electric revenues 2,259,594 4,223,027 1,323,043 594,417 1,488,955 Natural gas — 62,148 — 91,806 — Total operating revenues $2,259,594 $4,285,175 $1,323,043 $686,223 $1,488,955 (a) Sales for resale and competitive businesses sales include 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 revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late 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 years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125
Allowance For Doubtful Accounts [Table Text Block]	The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Utility operating companies’ total revenues for the year ended December 31, 2021 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $882,773 $1,484,612 $578,258 $269,891 $766,312 Commercial 480,401 1,055,825 439,950 208,104 425,927 Industrial 496,661 1,771,311 150,698 30,751 492,949 Governmental 19,112 82,503 46,248 71,584 26,238 Total billed retail 1,878,947 4,394,251 1,215,154 580,330 1,711,426 Sales for resale (a) 311,791 391,424 124,632 88,349 145,719 Other electric revenues (b) 130,443 148,304 58,357 1,813 41,805 Revenues from contracts with customers 2,321,181 4,933,979 1,398,143 670,492 1,898,950 Other revenues (c) 17,409 60,480 8,203 1,739 3,561 Total electric revenues 2,338,590 4,994,459 1,406,346 672,231 1,902,511 Natural gas — 73,989 — 96,621 — Total operating revenues $2,338,590 $5,068,448 $1,406,346 $768,852 $1,902,511 The Utility operating companies’ total revenues for the year ended December 31, 2020 were as follows: 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $841,162 $1,270,187 $523,379 $243,502 $672,087 Commercial 466,273 886,548 395,875 179,406 364,638 Industrial 461,907 1,314,234 145,100 24,248 385,681 Governmental 18,011 68,901 41,955 59,819 23,445 Total billed retail 1,787,353 3,539,870 1,106,309 506,975 1,445,851 Sales for resale (a) 173,115 333,594 77,530 33,213 100,273 Other electric revenues (b) 109,642 141,004 54,590 8,294 39,981 Revenues from contracts with customers 2,070,110 4,014,468 1,238,429 548,482 1,586,105 Other revenues (c) 14,384 4,595 9,425 12,150 1,020 Total electric revenues 2,084,494 4,019,063 1,247,854 560,632 1,587,125 Natural gas — 50,799 — 73,209 — Total operating revenues $2,084,494 $4,069,862 $1,247,854 $633,841 $1,587,125
Allowance For Doubtful Accounts [Table Text Block]	The following tables set forth a reconciliation of changes in the allowance for doubtful accounts for the years ended December 31, 2021 and 2020. Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 Provisions (a) 56.2 30.4 16.7 0.7 7.3 1.1 Write-offs (118.2) (38.9) (38.3) (15.7) (12.3) (13.0) Recoveries 12.9 3.3 5.1 2.7 0.9 0.9 Balance as of December 31, 2021 $68.6 $13.1 $29.2 $7.2 $13.3 $5.8 Entergy Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of December 31, 2019 $7.4 $1.2 $1.9 $0.6 $3.2 $0.5 Provisions (b) 109.0 16.2 43.7 18.8 14.1 16.2 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 9.9 2.7 3.6 1.3 1.1 1.2 Balance as of December 31, 2020 $117.7 $18.3 $45.7 $19.5 $17.4 $16.8 (a) Provisions include estimated incremental bad debt expenses, and revisions to those estimates, resulting from the COVID-19 pandemic of $30.4 million for Entergy, $22.2 million for Entergy Arkansas, $7.4 million for Entergy Louisiana, ($2.4) million for Entergy Mississippi, $4.3 million for Entergy New Orleans, and ($1.1) million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators. (b) Provisions include estimated incremental bad debt expenses resulting from the COVID-19 pandemic of $87.1 million for Entergy, $10.5 million for Entergy Arkansas, $36 million for Entergy Louisiana, $15.5 million for Entergy Mississippi, $12.2 million for Entergy New Orleans, and $12.9 million for Entergy Texas that have been deferred as regulatory assets. See Note 2 to the financial statements for discussion of the COVID-19 orders issued by retail regulators.

Summary Of Significant Accoun_4

Summary Of Significant Accounting Policies (Narrative) (Details) $ in Thousands	1 Months Ended			3 Months Ended		12 Months Ended
	Mar. 31, 2019$ / kWh	Mar. 31, 2018$ / kWh	Mar. 31, 2017$ / kWh	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2021USD ($)$ / kWhshares	Dec. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)shares
Income Tax Expense (Benefit)						$ 191,374	$ (121,506)	$ (169,825)
Depreciation rates on average depreciable property						2.70%	2.80%	2.80%
Depreciation rates on average depreciable utility property						2.70%	2.70%	2.60%
Depreciation rates on average depreciable non-utility property						7.50%	12.70%	18.30%
Accumulated depreciation of non-utility property						$ 200,000	$ 191,000
Construction expenditures in accounts payable						$ 723,000	$ 745,000
Options outstanding excluded from the calculation of diluted earnings per share | shares						1,013,320	523,999	173,290
Incremental Common Shares Attributable to Share-based Payment Arrangements | shares						400,000	500,000	600,000
Asset Retirement Obligations, Noncurrent						$ 4,757,084	$ 6,469,452
Asset Impairment Charges						263,625	26,623	$ 290,027
Asset Write-Offs, Impairments, And Related Charges						263,599	26,379	226,678
Assets, Fair Value Disclosure						6,005,000	9,122,000
Property, Plant and Equipment, Net						357,576	343,328
Decommissioning						306,411	381,861	400,802
Regulatory Liability, Noncurrent						2,643,845	2,323,851
Deferred Tax Equity Partnership Earnings
Regulatory Liability, Noncurrent						18,100	0
Entergy Wholesale Commodities [Member]
Income Tax Expense (Benefit)						(25,381)	104,937	(161,295)
Asset Write-Offs, Impairments, And Related Charges						264,000	19,000	290,000
Asset Write-Offs, Impairments, And Related Charges						263,625	26,623	290,027
Entergy Louisiana [Member]
Income Tax Expense (Benefit)						$ 120,409	$ (382,324)	$ 121,623
Depreciation rates on average depreciable property						2.40%	2.40%	2.40%
Accumulated depreciation of non-utility property						$ 188,500	$ 179,800
Construction expenditures in accounts payable						$ 507,900	460,500
Percentage Interest in River Bend						30.00%
Portion of percentage of interest of River Bend plant costs, generation, revenues and expenses operating the Louisiana retail deregulated portion of River Bend						15.00%
Rate At Which Electricity Sold To Retail Customers | $ / kWh						0.046
Limit above which incremental revenue shared between ratepayers and shareholders | $ / kWh						0.046
Asset Retirement Obligations, Noncurrent						$ 1,653,198	1,573,307
Assets, Fair Value Disclosure						2,144,500	2,528,900
Property, Plant and Equipment, Net						337,247	323,110
Decommissioning						68,575	65,225	$ 59,346
Regulatory Liability, Noncurrent						1,042,597	918,293
Entergy Texas [Member]
Income Tax Expense (Benefit)						$ 25,526	$ 3,042	$ (53,896)
Depreciation rates on average depreciable property						3.20%	3.10%	3.00%
Construction expenditures in accounts payable						$ 73,100	$ 116,800
Asset Retirement Obligations, Noncurrent						8,520	8,063
Assets, Fair Value Disclosure						27,400	286,400
Property, Plant and Equipment, Net						376	376
Regulatory Liability, Noncurrent						37,060	32,297
Entergy Arkansas [Member]
Income Tax Expense (Benefit)						$ 75,195	$ 47,777	$ (46,769)
Depreciation rates on average depreciable property						2.70%	2.60%	2.50%
Construction expenditures in accounts payable						$ 35,600	$ 59,700
Rate At Which Electricity Sold To Retail Customers | $ / kWh	0.01882	0.01547	0.01164
Asset Retirement Obligations, Noncurrent						1,390,410	1,314,160
Assets, Fair Value Disclosure						1,445,500	1,444,600
Decommissioning						77,696	73,319	$ 68,030
Regulatory Liability, Noncurrent						743,314	686,872
Entergy Arkansas [Member] | Deferred Tax Equity Partnership Earnings
Regulatory Liability, Noncurrent						18,100	0
Entergy Mississippi [Member]
Income Tax Expense (Benefit)						$ 45,323	$ 27,190	$ 30,866
Depreciation rates on average depreciable property						3.60%	3.50%	3.20%
Accumulated depreciation of non-utility property						$ 500	$ 500
Construction expenditures in accounts payable						26,500	31,400
Asset Retirement Obligations, Noncurrent						10,315	9,762
Assets, Fair Value Disclosure						96,800	65,200
Property, Plant and Equipment, Net						4,527	4,543
Regulatory Liability, Noncurrent						49,313	15,828
Entergy New Orleans [Member]
Income Tax Expense (Benefit)						$ 5,936	$ (4,207)	$ 186
Depreciation rates on average depreciable property						3.20%	3.10%	3.20%
Construction expenditures in accounts payable							$ 9,200
Asset Retirement Obligations, Noncurrent						$ 4,032	3,768
Assets, Fair Value Disclosure						44,900	86,500
Property, Plant and Equipment, Net						1,016	1,016
System Energy [Member]
Income Tax Expense (Benefit)						$ (1,977)	$ 20,543	$ 15,349
Depreciation rates on average depreciable property						1.90%	2.10%	2.10%
Construction expenditures in accounts payable						$ 23,400	$ 17,700
Asset Retirement Obligations, Noncurrent						1,007,603	968,910
Assets, Fair Value Disclosure						1,474,400	1,432,300
Decommissioning						38,693	37,181	$ 35,729
Regulatory Liability, Noncurrent						$ 744,944	$ 665,396
Vermont Yankee [Member]
After-Tax Asset Impairment Charge				$ 4,200
Vermont Yankee [Member] | Entergy Wholesale Commodities [Member]
Asset Impairment Charges					$ 173,000

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Schedule Of Net Property, Plant, And Equipment) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2021USD ($)MW	Dec. 31, 2020USD ($)
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	$ 9,578,000	$ 8,758,000
Distribution	12,877,000	10,805,000
Net Book Value	64,263,250	59,696,443
Construction work in progress	1,511,966	2,012,030
Nuclear fuel	577,000	601,000
Property, plant and equipment - net	42,244,160	38,852,777
Entergy Arkansas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,065,000	2,053,000
Distribution	2,801,000	2,666,000
Net Book Value	13,578,297	12,905,322
Construction work in progress	241,127	234,213
Nuclear fuel	182,000	163,000
Property, plant and equipment - net	$ 8,529,183	8,047,224
Entergy Arkansas [Member] | Independence Unit 1 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	822
Ownership	31.50%
Investment	$ 143,000
Accumulated Depreciation	$ 106,000
Entergy Arkansas [Member] | Independence Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	15.75%
Investment	$ 43,000
Accumulated Depreciation	$ 31,000
Entergy Arkansas [Member] | White Bluff Units 1 And 2 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	1,639
Ownership	57.00%
Investment	$ 587,000
Accumulated Depreciation	$ 390,000
Entergy Arkansas [Member] | Ouachita Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	66.67%
Investment	$ 173,000
Accumulated Depreciation	$ 156,000
Entergy Arkansas [Member] | Union Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	25.00%
Investment	$ 29,000
Accumulated Depreciation	9,000
Entergy Louisiana [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	4,237,000	3,756,000
Distribution	5,629,000	4,130,000
Net Book Value	28,055,038	25,619,789
Construction work in progress	847,924	667,281
Nuclear fuel	209,000	210,000
Property, plant and equipment - net	$ 19,537,134	17,387,718
Entergy Louisiana [Member] | Ouachita Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	33.33%
Investment	$ 91,000
Accumulated Depreciation	$ 78,000
Entergy Louisiana [Member] | Union Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	50.00%
Investment	$ 59,000
Accumulated Depreciation	$ 10,000
Entergy Louisiana [Member] | Roy S. Nelson Unit 6 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	521
Ownership	40.25%
Investment	$ 294,000
Accumulated Depreciation	$ 212,000
Entergy Louisiana [Member] | Roy S. Nelson Unit 6 Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	19.57%
Investment	$ 21,000
Accumulated Depreciation	$ 10,000
Entergy Louisiana [Member] | Big Cajun 2 Unit 3 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	540
Ownership	24.15%
Investment	$ 151,000
Accumulated Depreciation	$ 131,000
Entergy Louisiana [Member] | Big Cajun 2 Unit 3 Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	8.05%
Investment	$ 5,000
Accumulated Depreciation	$ 3,000
Entergy Louisiana [Member] | Acadia Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	50.00%
Investment	$ 21,000
Accumulated Depreciation	2,000
Entergy Mississippi [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	1,383,000	1,235,000
Distribution	1,879,000	1,651,000
Net Book Value	6,613,109	6,084,730
Construction work in progress	95,452	134,854
Nuclear fuel	0	0
Property, plant and equipment - net	$ 4,580,971	4,214,497
Entergy Mississippi [Member] | Independence Units 1 And 2 And Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	1,246
Ownership	25.00%
Investment	$ 286,000
Accumulated Depreciation	179,000
Entergy New Orleans [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	114,000	111,000
Distribution	702,000	576,000
Net Book Value	1,976,202	1,821,638
Construction work in progress	22,199	12,460
Nuclear fuel	0	0
Property, plant and equipment - net	$ 1,598,075	1,441,326
Entergy New Orleans [Member] | Union Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	25.00%
Investment	$ 29,000
Accumulated Depreciation	8,000
Entergy Texas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	1,743,000	1,566,000
Distribution	1,866,000	1,782,000
Net Book Value	7,181,567	6,007,687
Construction work in progress	183,965	879,908
Nuclear fuel	0	0
Property, plant and equipment - net	$ 5,315,782	5,023,101
Entergy Texas [Member] | Roy S. Nelson Unit 6 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	521
Ownership	29.75%
Investment	$ 208,000
Accumulated Depreciation	$ 120,000
Entergy Texas [Member] | Roy S. Nelson Unit 6 Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	14.47%
Investment	$ 7,000
Accumulated Depreciation	$ 3,000
Entergy Texas [Member] | Big Cajun 2 Unit 3 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	540
Ownership	17.85%
Investment	$ 113,000
Accumulated Depreciation	$ 84,000
Entergy Texas [Member] | Big Cajun 2 Unit 3 Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	5.95%
Investment	$ 4,000
Accumulated Depreciation	$ 1,000
Entergy Texas [Member] | Montgomery County Power Station
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Total Megawatt Capability | MW	909
Ownership	92.44%
Investment	$ 728,000
Accumulated Depreciation	18,000
System Energy [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	35,000	37,000
Distribution	0	0
Net Book Value	5,362,494	5,309,458
Construction work in progress	97,968	59,831
Nuclear fuel	171,000	175,000
Property, plant and equipment - net	$ 2,235,764	2,188,927
Ownership	90.00%
System Energy [Member] | Grand Gulf Unit 1 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Nuclear
Total Megawatt Capability | MW	1,404
Ownership	90.00%
Investment	$ 5,363,000
Accumulated Depreciation	3,317,000
Utility [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	9,577,000	8,758,000
Distribution	12,877,000	10,805,000
Construction work in progress	1,511,000	2,008,000
Nuclear fuel	563,000	548,000
Property, plant and equipment - net	42,162,000	38,674,000
Entergy Wholesale Commodities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	1,000	0
Distribution	0	0
Construction work in progress	1,000	4,000
Nuclear fuel	14,000	53,000
Property, plant and equipment - net	$ 77,000	171,000
Entergy Wholesale Commodities [Member] | Independence Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	7.18%
Investment	$ 20,000
Accumulated Depreciation	$ 14,000
Entergy Wholesale Commodities [Member] | Roy S. Nelson Unit 6 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	521
Ownership	10.90%
Investment	$ 118,000
Accumulated Depreciation	$ 69,000
Entergy Wholesale Commodities [Member] | Roy S. Nelson Unit 6 Common Facilities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	5.30%
Investment	$ 3,000
Accumulated Depreciation	$ 1,000
Entergy Wholesale Commodities [Member] | Independence Unit 2 [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Total Megawatt Capability | MW	424
Ownership	14.37%
Investment	$ 76,000
Accumulated Depreciation	55,000
Parent & Other [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	0	0
Distribution	0	0
Construction work in progress	0	0
Nuclear fuel	0	0
Property, plant and equipment - net	5,000	7,000
Nuclear Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	7,632,000	7,526,000
Nuclear Plant [Member] | Entergy Arkansas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	1,775,000	1,622,000
Nuclear Plant [Member] | Entergy Louisiana [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	3,941,000	3,980,000
Nuclear Plant [Member] | Entergy Mississippi [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Nuclear Plant [Member] | Entergy New Orleans [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Nuclear Plant [Member] | Entergy Texas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Nuclear Plant [Member] | System Energy [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	1,908,000	1,891,000
Nuclear Plant [Member] | Utility [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	7,624,000	7,493,000
Nuclear Plant [Member] | Entergy Wholesale Commodities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	8,000	33,000
Nuclear Plant [Member] | Parent & Other [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Other Plant In Service [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	7,158,000	6,346,000
Net Book Value	2,910,000	2,804,000
Other Plant In Service [Member] | Entergy Arkansas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	931,000	803,000
Net Book Value	534,000	506,000
Other Plant In Service [Member] | Entergy Louisiana [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	3,631,000	3,660,000
Net Book Value	1,042,000	984,000
Other Plant In Service [Member] | Entergy Mississippi [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	882,000	868,000
Net Book Value	342,000	325,000
Other Plant In Service [Member] | Entergy New Orleans [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	411,000	416,000
Net Book Value	349,000	326,000
Other Plant In Service [Member] | Entergy Texas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	1,250,000	523,000
Net Book Value	273,000	273,000
Other Plant In Service [Member] | System Energy [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Net Book Value	24,000	26,000
Other Plant In Service [Member] | Utility [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	7,105,000	6,270,000
Net Book Value	2,905,000	2,792,000
Other Plant In Service [Member] | Entergy Wholesale Commodities [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	53,000	76,000
Net Book Value	0	5,000
Other Plant In Service [Member] | Parent & Other [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Production	0	0
Net Book Value	$ 5,000	$ 7,000

Summary Of Significant Accoun_6

Summary Of Significant Accounting Policies (Schedule Of Depreciation Rates On Average Depreciable Property) (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Depreciation rates on average depreciable property	2.70%	2.80%	2.80%
Entergy Arkansas [Member]
Depreciation rates on average depreciable property	2.70%	2.60%	2.50%
Entergy Louisiana [Member]
Depreciation rates on average depreciable property	2.40%	2.40%	2.40%
Entergy Mississippi [Member]
Depreciation rates on average depreciable property	3.60%	3.50%	3.20%
Entergy New Orleans [Member]
Depreciation rates on average depreciable property	3.20%	3.10%	3.20%
Entergy Texas [Member]
Depreciation rates on average depreciable property	3.20%	3.10%	3.00%
System Energy [Member]
Depreciation rates on average depreciable property	1.90%	2.10%	2.10%

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Schedule Of Subsidiaries' Investment And Accumulated Depreciation In Generating Stations) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
System Energy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	90.00%
Independence Unit 1 [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	31.50%
Investment	$ 143
Accumulated Depreciation	$ 106
Independence Common Facilities [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	15.75%
Investment	$ 43
Accumulated Depreciation	$ 31
Independence Common Facilities [Member] | Entergy Wholesale Commodities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	7.18%
Investment	$ 20
Accumulated Depreciation	$ 14
White Bluff Units 1 And 2 [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	57.00%
Investment	$ 587
Accumulated Depreciation	$ 390
Ouachita Common Facilities [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	66.67%
Investment	$ 173
Accumulated Depreciation	$ 156
Ouachita Common Facilities [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	33.33%
Investment	$ 91
Accumulated Depreciation	$ 78
Roy S. Nelson Unit 6 [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	40.25%
Investment	$ 294
Accumulated Depreciation	$ 212
Roy S. Nelson Unit 6 [Member] | Entergy Texas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	29.75%
Investment	$ 208
Accumulated Depreciation	$ 120
Roy S. Nelson Unit 6 [Member] | Entergy Wholesale Commodities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	10.90%
Investment	$ 118
Accumulated Depreciation	$ 69
Roy S. Nelson Unit 6 Common Facilities [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	19.57%
Investment	$ 21
Accumulated Depreciation	$ 10
Roy S. Nelson Unit 6 Common Facilities [Member] | Entergy Texas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	14.47%
Investment	$ 7
Accumulated Depreciation	$ 3
Roy S. Nelson Unit 6 Common Facilities [Member] | Entergy Wholesale Commodities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	5.30%
Investment	$ 3
Accumulated Depreciation	$ 1
Big Cajun 2 Unit 3 [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	24.15%
Investment	$ 151
Accumulated Depreciation	$ 131
Big Cajun 2 Unit 3 [Member] | Entergy Texas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	17.85%
Investment	$ 113
Accumulated Depreciation	$ 84
Big Cajun 2 Unit 3 Common Facilities [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	8.05%
Investment	$ 5
Accumulated Depreciation	$ 3
Big Cajun 2 Unit 3 Common Facilities [Member] | Entergy Texas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	5.95%
Investment	$ 4
Accumulated Depreciation	$ 1
Acadia Common Facilities [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	50.00%
Investment	$ 21
Accumulated Depreciation	$ 2
Independence Units 1 And 2 And Common Facilities [Member] | Entergy Mississippi [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	25.00%
Investment	$ 286
Accumulated Depreciation	$ 179
Grand Gulf Unit 1 [Member] | System Energy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Nuclear
Ownership	90.00%
Investment	$ 5,363
Accumulated Depreciation	$ 3,317
Independence Unit 2 [Member] | Entergy Wholesale Commodities [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Coal
Ownership	14.37%
Investment	$ 76
Accumulated Depreciation	$ 55
Ouachita Units 1 and 2 [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	100.00%
Ouachita Unit 3 [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	100.00%
Union Common Facilities [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	25.00%
Investment	$ 29
Accumulated Depreciation	$ 9
Union Common Facilities [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	50.00%
Investment	$ 59
Accumulated Depreciation	$ 10
Union Common Facilities [Member] | Entergy New Orleans [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Utility Plant Fuel Type	Gas
Ownership	25.00%
Investment	$ 29
Accumulated Depreciation	$ 8
Union Unit 1 [Member] | Entergy New Orleans [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	100.00%
Union Unit 2 [Member] | Entergy Arkansas [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	100.00%
Union Units 3 and 4 [Member] | Entergy Louisiana [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership	100.00%

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Basic earnings per share
Net Income (Loss) Attributable to Parent	$ 1,118,492	$ 1,388,334	$ 1,241,226
Net Income Attributable to Entergy Corporation, Shares	200,941,511	200,106,945	195,195,858
Basic earnings per share (in usd per share)	$ 5.57	$ 6.94	$ 6.36
Average dilutive effect of:
Stock options, Shares	400,000	500,000	600,000
Stock options $/share	$ (0.01)	$ (0.02)	$ (0.02)
Average Dilutive Effect Of Restricted Stock Shares	600,000	500,000	800,000
Average Dilutive Effect Of Restricted Stock Per Share	$ (0.02)	$ (0.02)	$ (0.03)
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	0	0	400,000
Average Dilutive Effect Of Equity Forwards	$ 0	$ 0	$ (0.01)
Diluted earnings per share, Shares	201,873,024	201,102,220	196,999,284
Diluted earnings per share (in usd per share)	$ 5.54	$ 6.90	$ 6.30

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details)	Oct. 26, 2021USD ($)	Jul. 31, 2019USD ($)	Jan. 01, 2018USD ($)	Feb. 28, 2022USD ($)	Dec. 31, 2021USD ($)	Oct. 31, 2021USD ($)	Sep. 30, 2021USD ($)	Aug. 31, 2021USD ($)	Jul. 31, 2021USD ($)	Jun. 30, 2021USD ($)	May 31, 2021USD ($)	Apr. 30, 2021USD ($)	Mar. 31, 2021USD ($)	Feb. 28, 2021USD ($)	Dec. 31, 2020USD ($)	Nov. 30, 2020USD ($)	Oct. 31, 2020USD ($)	Sep. 30, 2020USD ($)	Jul. 31, 2020USD ($)	Jun. 30, 2020USD ($)	May 31, 2020USD ($)	Apr. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Feb. 29, 2020USD ($)	Jan. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Nov. 30, 2019USD ($)	Oct. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Aug. 31, 2019USD ($)	Jul. 31, 2019USD ($)	Jun. 30, 2019USD ($)	May 31, 2019USD ($)	Mar. 31, 2019USD ($)$ / kWh	Jan. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Oct. 31, 2018USD ($)	Sep. 30, 2018	Aug. 31, 2018USD ($)	Jul. 31, 2018USD ($)	May 31, 2018USD ($)	Mar. 31, 2018USD ($)$ / kWh	Feb. 28, 2018USD ($)	Dec. 31, 2017USD ($)	Mar. 31, 2017USD ($)$ / kWh	Jan. 31, 2017	Apr. 30, 2016	May 31, 2015USD ($)	Aug. 31, 2014USD ($)$ / unitshares	Jun. 30, 2014USD ($)	Jan. 31, 2014USD ($)	Jul. 31, 2010USD ($)$ / unitshares	Jun. 30, 2010USD ($)	Aug. 31, 2008USD ($)$ / unitshares	Jul. 31, 2008USD ($)shares	Apr. 30, 2007USD ($)	Aug. 31, 2020USD ($)	Mar. 31, 2021USD ($)	Oct. 31, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2021USD ($)	Aug. 31, 2020USD ($)	Dec. 31, 2020USD ($)	Jun. 30, 2021USD ($)	Jul. 31, 2021USD ($)	Dec. 31, 2022USD ($)	Mar. 31, 2022USD ($)	Dec. 31, 2021USD ($)$ / kWh	Mar. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017	Apr. 23, 2018	Aug. 31, 2024USD ($)	Aug. 31, 2024USD ($)	Mar. 31, 2019USD ($)	Sep. 30, 2021USD ($)	Jan. 31, 2022USD ($)	Nov. 30, 2021USD ($)	Apr. 30, 2010USD ($)	Aug. 26, 2008USD ($)	Jul. 29, 2008USD ($)	Apr. 30, 2008USD ($)
Regulatory Assets [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent			21.00%																																																																						35.00%	35.00%
Asset Write-Offs, Impairments, And Related Charges																																																																				$ 263,599,000		$ 26,379,000		$ 226,678,000
Payments to Acquire Other Property, Plant, and Equipment																																																																				(168,304,000)		(247,121,000)		(305,472,000)
Deferred Fuel Cost					$ 324,394,000										$ 4,380,000																																														$ 324,394,000		$ 4,380,000					324,394,000		4,380,000
Regulatory Assets, Noncurrent					6,613,256,000										6,076,549,000																																														6,613,256,000		6,076,549,000					6,613,256,000		6,076,549,000
Regulatory Liability, Noncurrent					2,643,845,000										2,323,851,000																																														2,643,845,000		2,323,851,000					2,643,845,000		2,323,851,000
Increase (Decrease) in Regulatory Liabilities																																																																				43,631,000		238,669,000		(14,781,000)
Construction work in progress					1,511,966,000										2,012,030,000																																														1,511,966,000		2,012,030,000					1,511,966,000		2,012,030,000
Long-term debt																																																																				8,308,427,000		12,619,201,000		9,304,396,000
Other Regulatory Charges Credits Net																																																																				111,628,000		14,609,000		(26,220,000)
Entergy Wholesale Commodities [Member]
Regulatory Assets [Line Items]
Asset Write-Offs, Impairments, And Related Charges																																																																				264,000,000		19,000,000		290,000,000
Asset Write-Offs, Impairments, And Related Charges																																																																				263,625,000		26,623,000		290,027,000
Construction work in progress					1,000,000										4,000,000																																														1,000,000		4,000,000					1,000,000		4,000,000
Cash collateral posted					8,000,000										5,000,000																																														8,000,000		5,000,000					8,000,000		$ 5,000,000
Hurricane Ida
Regulatory Assets [Line Items]
Construction work in progress					1,600,000,000																																																								1,600,000,000							$ 1,600,000,000
Total Restoration Costs For Repair and Replacement of Electrical System								$ 2,700,000,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent																																																																						21.00%
Rate Increase Included in Formula Rate Plan																																	$ 109,500,000							$ 4,800,000																																103,000,000
Formula rate plan increase excluding Tax Cuts and Jobs Act Credits																																								$ 98,000,000
Bond proceeds loaned by LCDA to LURC under Louisiana Act 55 financing																																																	$ 309,000,000
Annual customer credits																																																		$ 6,200,000
LCDA issuance of bonds under Louisiana Act 55 financing																																																	314,850,000
Amount transfered to restricted escrow account as storm damage reserve																																																	16,000,000
Amortization period of cost																																																																				27 years
Earned Return on Common Equity Resulting From Revenue-Neutral Realignments to Other Recovery Mechanisms																																								8.16%
Earned Return on Common Equity Excluding Realignments																																								9.88%
Earned return on common equity																																																																									10.61%
Income before income taxes																																																																				$ 774,393,000		$ 700,028,000		$ 813,160,000
Deferred Fuel Cost					45,374,000										2,250,000																																														45,374,000		2,250,000					45,374,000		2,250,000
Minimum customer benefits																																																		$ 30,800,000
Bond proceeds transfered to company under Louisiana Act 55 financing																																																	$ 293,000,000
Regulatory Assets, Noncurrent					2,776,666,000										1,726,066,000																																														2,776,666,000		1,726,066,000					2,776,666,000		1,726,066,000
Refund to customers related to claim of vendor fault in servicing nuclear plant for Entergy Gulf States Louisiana business																																			$ 900,000
Refund to customers related to claim of vendor fault in servicing nuclear plant																											$ 2,300,000			$ 4,300,000					$ 7,300,000
Public Utilities, Requested Return on Equity, Percentage																					9.80%																																																			9.66%
Regulatory Liability, Noncurrent					1,042,597,000										918,293,000																																														1,042,597,000		918,293,000					$ 1,042,597,000		918,293,000
Public Utilities, Requested Rate Increase (Decrease), Amount																																	118,700,000																																					63,000,000
Rate At Which Electricity Sold To Retail Customers | $ / kWh																																																																				0.046
Formula rate plan revenue decrease																																							$ 17,600,000																																		$ 8,900,000
Increase (Decrease) in Regulatory Liabilities																																																																				$ (16,478,000)		71,698,000		$ (35,881,000)
Monthly regulatory liability established to reflect tax benefits already included in retail rates			$ 9,100,000
Regulatory asset related to costs associated with COVID-19 pandemic					56,300,000																																																								56,300,000							56,300,000
Projected increase in revenue requirement														$ 1,200,000	35,000,000																																																108,000,000
Bandwidth around midpoint of return on equity																					6000.00%
Construction work in progress					847,924,000										667,281,000																																														847,924,000		667,281,000					847,924,000		667,281,000
Amount transfer from restricted escrow account as storm damage reserve																$ 257,000,000
Long-term debt					1,200,000,000																																																															3,769,166,000		3,675,083,000		2,691,133,000
Increase (Reduction) in income tax resulting from Act 55 financing settlement																																																										$ 32,000,000		$ 32,000,000
Reduction of income tax expense due reversal of UTPs																																																										58,000,000		58,000,000
Increase to income tax expense due to reduction of the DTA																																																										26,000,000
Regulatory charge due to LPSC Act 55 Financing Order - Gross																																																										29,000,000		29,000,000
Regulatory charge due to LPSC Act 55 Financing Order - Net of Tax																																																										$ 21,000,000		$ 21,000,000
Estimated remaining costs for completion of J. Wayne Leonard Power Station														3,100,000
Interest income excluded in 2019 FRP filing																					$ 251,000
Storm Reserve Escrow Account												$ 290,000,000
Aggregate principal amount of system restoration bonds authorization requested					3,180,000,000																																																								3,180,000,000							3,180,000,000
Deferred Fuel Cost - Net Asset					213,500,000										170,400,000																																														213,500,000		170,400,000					213,500,000		170,400,000
Other Regulatory Charges Credits Net																																																																				38,245,000		(584,000)		(105,203,000)
Estimated remaining costs for completion of J. Wayne Leonard Power Station														3,100,000
Interest income excluded in 2019 FRP filing																					251,000
Storm Reserve Escrow Account												290,000,000
Aggregate principal amount of system restoration bonds authorization requested					3,180,000,000																																																								3,180,000,000							3,180,000,000
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Six Two Percent Series Due November Two Thousand Twenty Three
Regulatory Assets [Line Items]
Long-term Debt, Gross					$ 1,100,000,000										1,100,000,000																																														$ 1,100,000,000		1,100,000,000					$ 1,100,000,000		1,100,000,000
Debt Instrument, Interest Rate, Stated Percentage					0.62%																																																								0.62%							0.62%
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Six Two Percent Series Due November 2023
Regulatory Assets [Line Items]
Long-term debt																$ 1,100,000,000
Debt Instrument, Interest Rate, Stated Percentage																0.62%
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Nine Five Percent Series Due October 2024
Regulatory Assets [Line Items]
Long-term debt						$ 1,000,000,000
Entergy Louisiana [Member] | Hurricane Rita [Member]
Regulatory Assets [Line Items]
Reduction to Louisiana Act 55 financing savings obligation regulatory liability due to Tax Cuts and Jobs Act																										$ 22,300,000																																														22,300,000
Minimum amount of benefits committed to pass on to the customers																																																																																					$ 40,000,000
Prospective Annual rate reductions for five years																																																																																					$ 8,000,000
Bond issued by LCDA																																																																																				$ 687,700,000
Amount transfer to restricted escrow account as storm damage reserve by corporation																																																							$ 152,000,000
Amount Transferred to Entergy Louisiana																																																							527,000,000
Proceed from loan by LCDA to corporation LURC																																																							679,000,000
Amount used to acquire membership interest units in wholly owned Subsidiary																																																							$ 545,000,000
Class preferred, non-voting, membership interest units | shares																																																							5,449,861.85
Annual distribution rate																																																							10.00%
Amount withdrawn from restricted escrow account as approved by units of wholly owned subsidiary																																																							$ 17,800,000
Entergy Louisiana [Member] | Hurricane Gustav and Ike [Member]
Regulatory Assets [Line Items]
Reduction to Louisiana Act 55 financing savings obligation regulatory liability due to Tax Cuts and Jobs Act																										2,700,000																																														2,700,000
Minimum amount of benefits committed to pass on to the customers																																																																																		$ 43,300,000
Prospective Annual rate reductions for five years																																																																																		$ 8,700,000
Bond issued by LCDA																																																				$ 713,000,000
Amount transfer to restricted escrow account as storm damage reserve by corporation																																																				290,000,000
Amount Transferred to Entergy Louisiana																																																				412,700,000
Proceed from loan by LCDA to corporation LURC																																																				702,700,000
Amount used to acquire membership interest units in wholly owned Subsidiary																																																				$ 412,700,000
Class preferred, non-voting, membership interest units | shares																																																				4,126,940.15
Annual distribution rate																																																				9.00%
Liquidation price per unit | $ / unit																																																				100
Net worth required under terms of membership interest																																																				$ 1,000,000,000
Entergy Louisiana [Member] | Winter Storm Uri
Regulatory Assets [Line Items]
Fuel Costs														166,000,000
Fuel Costs														166,000,000
Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri
Regulatory Assets [Line Items]
Deferred Storm and Property Reserve Deficiency, Noncurrent												1,680,000,000
Non-capital storm costs												380,000,000
Total Restoration Costs For Repair and Replacement of Electrical System												2,060,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs												2,110,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs												2,110,000,000
Entergy Louisiana [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Deferred Storm and Property Reserve Deficiency, Noncurrent					$ 1,000,000,000																																																								$ 1,000,000,000							$ 1,000,000,000
Construction work in progress					1,500,000,000																																																								1,500,000,000							$ 1,500,000,000
Storm Reserve Escrow Account							$ 1,000,000,000																																																																								$ 1,000,000,000
Storm Reserve Escrow Account							1,000,000,000																																																																								1,000,000,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																6.93%		6.94%																																							7.13%
Amortization period of cost																																																																				27 years
Earned return on common equity																																																																									7.81%
Authorized Storm Damage Reserve Balance					15,000,000																																																								15,000,000							$ 15,000,000
Monthly storm damage provision																																																																				1,750,000
Balance At Which Storm Damage Accrual Will Return To Current Level																																	$ 10,000,000																																			10,000,000
Income before income taxes																																																																				212,157,000		167,773,000		150,791,000
Deferred Fuel Cost					121,878,000										0																																														121,878,000		0					121,878,000		0
Projected under-recovery Energy Cost Recovery Rider																													$ 57,000,000
Projected Over-Recovery Energy Cost Recovery Rider																$ 24,400,000											$ 39,600,000																																																						$ 80,600,000
Regulatory Assets, Noncurrent					462,432,000										467,341,000																																														462,432,000		467,341,000					462,432,000		467,341,000
Regulatory Liability, Noncurrent					49,313,000										15,828,000																																														49,313,000		15,828,000					49,313,000		15,828,000
Public Utilities, Requested Rate Increase (Decrease), Amount																																		$ 36,800,000																																							$ 10,100,000
Public Utilities, Approved Rate Increase (Decrease), Amount																																$ 32,800,000																																									11,000,000
Increase (Decrease) in Regulatory Liabilities																																																																				21,930,000		(18,672,000)		(21,524,000)
Regulatory asset related to costs associated with COVID-19 pandemic					15,000,000																																																								15,000,000							15,000,000
Recovery of first-year revenue requirement for certain costs of Choctaw Generating Station																									$ 59,000,000
Vegetation management cost rider																						$ 22,000,000
Construction work in progress					95,452,000										134,854,000																																														95,452,000		134,854,000					95,452,000		134,854,000
Interim adjustment to energy cost recovery rider credit to customers																					50,000,000
Long-term debt																																																																				398,284,000		165,385,000		437,153,000
Deferred Fuel Cost - Net Asset					121,900,000																																																								121,900,000							121,900,000
Other Regulatory Charges Credits Net																																																																				$ 5,913,000		$ (15,219,000)		14,993,000
Entergy Gulf States Louisiana [Member] | Hurricane Rita [Member]
Regulatory Assets [Line Items]
Bond issued by LCDA																																																																																			$ 278,400,000
Amount transfer to restricted escrow account as storm damage reserve by corporation																																																						$ 87,000,000
Amount Transferred to Entergy Louisiana																																																						187,700,000
Proceed from loan by LCDA to corporation LURC																																																						274,700,000
Amount used to acquire membership interest units in wholly owned Subsidiary																																																						$ 189,400,000
Class preferred, non-voting, membership interest units | shares																																																						1,893,918.39
Annual distribution rate																																																						10.00%
Liquidation price per unit | $ / unit																																																						100
Net worth required under terms of membership interest																																																						$ 1,000,000,000
Amount withdrawn from restricted escrow account as approved by units of wholly owned subsidiary																																																						$ 1,700,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																																																						9.35%
Amortization period of cost																																																																				27 years
Earned return on common equity																																																																						6.26%
Amount of Hurricane Issac storm cost to be recovered through securitization																																																$ 31,800,000
Replenishment amount for storm reserve spending																																																63,900,000
Income before income taxes																																																																				$ 37,734,000		$ 45,131,000		52,815,000
Deferred Fuel Cost					0										2,130,000																																														0		2,130,000					0		2,130,000
Repayment of long-term payable due to Entergy Louisiana																																																																				(1,618,000)		(1,838,000)		(1,979,000)
Regulatory Assets, Noncurrent					248,617,000										$ 266,790,000																																														248,617,000		$ 266,790,000					248,617,000		266,790,000
Up Front Financing Costs On Issuance Of Bonds To Recover Storm Damage Restoration Costs																																																$ 3,000,000
Public Utilities, Requested Rate Increase (Decrease), Amount									$ 64,000,000															$ 45,000,000		45,000,000		$ 39,000,000
Provision for Rate Refund																										10,000,000																																														10,000,000
Regulatory Assets for Rate Case Costs and Algiers Customer Migration Costs																										12,000,000																																														12,000,000
Regulatory Assets for Retired General Plant Costs																										10,000,000																																														10,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 49,500,000
Increase (Decrease) in Regulatory Liabilities																																																																				4,985,000		$ (4,728,000)		(22,105,000)
Benefit to electric customers related to reduction in income tax expense under Tax Act																																										$ 8,200,000
Benefit to gas customers related to reduction in income tax expense under Tax Act																																										$ 1,300,000
Percent Equity in Proposed Common Equity Ratio																																																																						51.00%
Percent Debt in Proposed Common Equity Ratio																																																																						49.00%
FERC staff argued over-recovery in depreciation expense for capital additions																																																																						$ 2,200,000
Regulatory asset related to costs associated with COVID-19 pandemic					17,400,000																																																								17,400,000							17,400,000
Common Equity Tier One Capital Ratio															0.50																																																0.50							0.50
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service																																																																						2.00%
Proposed public utilities, property, plant, and equipment, disclosure of composite depreciation rate for plants in service																																																																						3.00%
Proposed recovery of certain rate case expenses																																																																						$ 1,400,000
Opportunity Sales Refund to be Redirected to Cares Program																				$ 7,000,000
Non-Securitized Storm Reserves Reallocated to Cares Program																				15,000,000
public utilities proposed customer credits																			$ 100
Credits to customer bills resulting from City Council Cares Program					4,300,000																																																								4,300,000							4,300,000
Construction work in progress					22,199,000										$ 12,460,000																																														22,199,000		$ 12,460,000					22,199,000		12,460,000
Long-term debt																																																																				183,403,000		138,925,000		113,876,000
Withdrawal from storm reserves													$ 44,000,000
Storm Reserve Escrow Account					0										83,038,000																																														0		83,038,000					0		83,038,000
Deferred Fuel Cost - Net Asset															6,200,000																																																6,200,000							6,200,000
Other Regulatory Charges Credits Net																																																																				13,177,000		1,854,000		21,616,000
Storm Reserve Escrow Account					0										83,038,000																																														0		83,038,000					0		83,038,000
Entergy New Orleans [Member] | Hurricane Zeta
Regulatory Assets [Line Items]
Deferred Storm and Property Reserve Deficiency, Noncurrent											$ 28,000,000
Non-capital storm costs											8,000,000
Total Restoration Costs For Repair and Replacement of Electrical System											$ 36,000,000
Entergy New Orleans [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Construction work in progress					120,000,000																																																								120,000,000							120,000,000
Amount transfer from restricted escrow account as storm damage reserve							39,000,000
Entergy Texas [Member]
Regulatory Assets [Line Items]
Portion of requested increase in base rates associated with moving costs																																									$ 48,000,000
Income before income taxes																																																																				254,350,000		218,115,000		105,501,000
Deferred Fuel Cost					48,280,000										0																																														48,280,000		0					48,280,000		0
Regulatory Assets, Noncurrent					421,333,000										524,713,000																																														421,333,000		524,713,000					421,333,000		524,713,000
Jurisdictional eligible fuel and purchased power expenses, net of credits																																																																														$ 1,600,000,000
Estimated deferred fuel under recovery balance for reconciliation period																													$ 25,800,000
Public Utilities, Requested Increase in Revenue Requirement																																									118,000,000
Regulatory Liability, Noncurrent					37,060,000										32,297,000																																														37,060,000		32,297,000					37,060,000		32,297,000
Public Utilities, Requested Rate Increase (Decrease), Amount																																				$ 2,700,000					166,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount																																					$ 53,200,000
Increase (Decrease) in Regulatory Liabilities																																																																				(28,747,000)		(57,477,000)		(105,517,000)
Return of excess ADIT through customer bill credits																																					185,200,000				185,200,000
Net book value of Neches and Sabine 2 plants																																					24,500,000
Deferred Storm and Property Reserve Deficiency, Noncurrent																																					20,500,000
Refund due customers resulting from lower federal income tax rate																																					25,000,000				25,000,000
Capitalized skylining tree hazard costs																																					6,000,000
Refund to customers of protected excess accumulated deferred taxes																																					242,500,000				$ 242,500,000
Regulatory asset related to costs associated with COVID-19 pandemic					11,700,000																																																								11,700,000							11,700,000
Construction work in progress					183,965,000										879,908,000																																														183,965,000		879,908,000					183,965,000		879,908,000
Replacement power costs associated with generation outages																																																																														2,000,000
Costs associated with the operation of the Spindletop natural gas storage facility																																																																														24,400,000
Non-specific disallowance of fuel and purchased power expenses																				$ 1,200,000
Interim fuel refund, including interest																																																											$ 25,500,000
Long-term debt																																																																				127,931,000		937,725,000		986,019,000
Interim fuel refund for cumulative over-recovery														75,000,000
Deferred Fuel Cost - Net Asset					48,300,000																																																								48,300,000							48,300,000
Other Regulatory Charges Credits Net																																																																				$ 59,581,000		90,398,000		88,770,000
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Regulatory Assets [Line Items]
Deferred Storm and Property Reserve Deficiency, Noncurrent												200,000,000
Non-capital storm costs												50,000,000
Total Restoration Costs For Repair and Replacement of Electrical System					243,000,000							250,000,000
Entergy Texas [Member] | Hurricane Rita [Member]
Regulatory Assets [Line Items]
Financing order authorized to issue storm cost recovery bonds																																																								$ 353,000,000
Entergy Texas [Member] | Hurricane Harvey
Regulatory Assets [Line Items]
Remaining restoration costs for repair and replacement of electrical system; previously-approved					13,000,000							13,000,000
Remaining restoration costs for repair and replacement of electrical system; previously-approved					13,000,000							$ 13,000,000
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Regulatory Assets [Line Items]
Amount to be charged to storm reserve and excluded from securitization							4,300,000
Black box amount to be excluded from securitization							5,000,000
Audit attestation costs to be excluded from securitization							300,000
Amount to be charged to storm reserve and excluded from securitization							4,300,000
Black box amount to be excluded from securitization							5,000,000
Audit attestation costs to be excluded from securitization							$ 300,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Incremental Fuel and Replacement Energy Costs																																																			$ 65,900,000
Amortization period of cost																																																																				27 years
Payments to Acquire Other Property, Plant, and Equipment																																																																				$ (131,770,000)		(5,988,000)		0
Refund to Customers Credited Through Formula Rate Plan																																																																									46,600,000
Income before income taxes																																																																				373,679,000		293,009,000		216,195,000
Deferred Fuel Cost					108,862,000										0																																														108,862,000		0					108,862,000		0
Regulatory Assets, Noncurrent					1,689,678,000										1,832,384,000																																														1,689,678,000		1,832,384,000					$ 1,689,678,000		1,832,384,000
Up Front Financing Costs On Issuance Of Bonds To Recover Storm Damage Restoration Costs																																																					$ 4,600,000
Public Utilities, Requested Return on Equity, Percentage		9.75%																																																																		9.75%
Proposed rate reduction in revised filing																												10,100,000
Regulatory asset related to scrubber costs incurred at White Bluff plant		$ 11,200,000																													$ 11,200,000
Regulatory Liability, Noncurrent					743,314,000										686,872,000																																														743,314,000		686,872,000					$ 743,314,000		686,872,000
Portion of Approved Revenue Requirement Increase Subject to Possible Future Adjustment and Refund to Customers																																					$ 45,700,000
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 15,300,000																										14,000,000
ALJ Recommended Percentage By Which Payments Be Reduced																																															20.00%
Liability Recorded Related to Estimated Payments Due Utility Operating Companies																																				35,000,000									$ 87,000,000																												35,000,000
Regulatory Asset Recorded to Represent Estimate of Recoverable Retail Portion of Costs																																				31,000,000									$ 75,000,000																												31,000,000
Rate At Which Electricity Sold To Retail Customers | $ / kWh																																		0.01882								0.01547			0.01164
Increase in Rate At Which Electricity Sold To Retail Customers | $ / kWh																																		0.01462								0.01882			0.01547
Increase (Decrease) in Regulatory Liabilities																																																																				21,066,000		106,878,000		39,293,000
Tax benefits to customers resulting from tax adjustment rider														$ 5,600,000																													$ 467,000,000
Refund to customers, plus interest, associated with recalculated bandwidth remedy																			13,700,000
Requested revenue increase resulting from settlement agreement																	$ 68,400,000
Reduced proposed revenue increase resulting from new methodology																	72,600,000																																																			1,000,000
Regulatory asset related to costs associated with COVID-19 pandemic					32,600,000																																																								32,600,000							32,600,000
Construction work in progress					241,127,000										234,213,000																																														241,127,000		234,213,000					241,127,000		234,213,000
Energy Cost Recovery Rider Rate Per kWh																																																																					$ 0.01052		$ 0.01462
Reduced proposed increase in revenue requirement to comply with annual revenue constraint						72,100,000			$ 72,400,000								74,300,000		$ 74,300,000
Annual revenue constraint per rate class percentage									400.00%										400.00%
Long-term debt																																																																				719,284,000		1,071,121,000		834,038,000
Projected Revenue Deficiency																																																																						61,900,000
Deferred Fuel Cost - Net Asset					177,600,000										15,200,000																																														177,600,000		15,200,000					177,600,000		15,200,000
Other Regulatory Charges Credits Net																																																																				$ (31,501,000)		(35,310,000)		(11,186,000)
System Energy [Member]
Regulatory Assets [Line Items]
Incremental Fuel and Replacement Energy Costs													$ 360,000,000
Earned return on common equity																																																																				10.94%
Income before income taxes																																																																				$ 104,837,000		119,674,000		114,469,000
Recommended adjustment to earned return on equity													9.32%
Percent Interest in Grand Gulf																																																																				90.00%
Annual renewal lease payments on Grand Gulf Sale-Leaseback																																		$ 17,200,000
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback																												$ 512,000,000
Regulatory Assets, Noncurrent					395,546,000										538,963,000																																														395,546,000		538,963,000					$ 395,546,000		538,963,000
Regulatory Liability, Noncurrent					744,944,000										665,396,000																																														744,944,000		665,396,000					744,944,000		665,396,000
Provision for Rate Refund					37,000,000																																																								37,000,000							37,000,000
Increase (Decrease) in Regulatory Liabilities																																																																				40,884,000		140,965,000		130,949,000
FERC staff argued over-recovery in depreciation expense for capital additions																														$ 32,000,000
First refund period requested authorized rate of return - LPSC																				7.97%
First refund period requested authorized rate of return - MPSC and APSC																				9.24%
First refund period requested authorized rate of return - FERC																				9.49%
Second refund period requested authorized rate of return - MPSC and APSC																				9.15%
Second refund period requested authorized rate of return - LPSC																				7.78%
Second refund period requested authorized rate of return - FERC																				9.09%
First refund period requested authorized rate of return																				10.12%
Second refund period requested authorized rate of return																				9.44%
Interest Portion of LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback					216,000,000																																																								216,000,000							216,000,000
Remaining NBV of Leased Assets																						70,000,000
Refund of Lease Payments																						$ 17,200,000
Rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback					422,000,000																																																								422,000,000							422,000,000
Interest Portion of rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback					128,000,000																																																								128,000,000							128,000,000
Refund related to depreciation expense adjustments					$ 19,000,000																																																								$ 19,000,000							$ 19,000,000
Future nuclear decommissioning costs allowed by the IRS in cost of goods sold																		$ 102,000,000
Percent of requested deduction allowed by IRS of uncertain decommissioning tax postion					10.00%																																																								10.00%							10.00%
Construction work in progress					$ 97,968,000										59,831,000																																														$ 97,968,000		59,831,000					$ 97,968,000		59,831,000
Additional unprotected excess ADIT related to uncertain decommissioning tax deduction																			$ 147,000,000
Proposed credit of excess accumulated deferred income taxes resulting from decommissioning uncertain tax position																	17,800,000																																										$ 17,800,000
Long-term debt																																																																				662,423,000		1,147,903,000		1,103,917,000
One-time accumulated deferred income tax credit															25,200,000
Accumulated deferred income tax credits to customers															$ 3,400,000
Other Regulatory Charges Credits Net																																																																				26,214,000		(26,531,000)		(35,210,000)
Estimated Return On Equity Complaint Refund					60,000,000																																																								60,000,000							60,000,000
Return On Equity Complaint - Estimated Annual Rate Reduction					45,000,000																																																								45,000,000							$ 45,000,000
Pre-authorization amount for capital improvement projects													$ 125,000,000
System Energy [Member] | First Refund Period [Member]
Regulatory Assets [Line Items]
LPSC requested authorized return on equity for System Energy in return on equity proceeding																								8.44%						7.81%					7.81%
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding																								8.41%											8.24%
FERC requested authorized return on equity for System Energy in return on equity proceeding																																	9.89%
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding																														8.26%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal																								9.22%					9.40%
Requested return on equity based on alternative methodology																																																																											10.26%
System Energy [Member] | Second refund period [Member]
Regulatory Assets [Line Items]
LPSC requested authorized return on equity for System Energy in return on equity proceeding																								7.89%						7.97%					7.97%
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding																								8.01%											8.41%
Public utilities requested return on equity percentage, median 2nd refund period																																9.65%
Public utilities requested return on equity percentage, midpoint 2nd refund period																																9.74%
Modified public utilities requested return on equity percentage based on benchmarks, median 2nd refund period																																9.91%
Modified public utilities requested return on equity percentage based on benchmarks, midpoint 2nd refund period																																10.30%
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding																														8.32%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal																								8.66%					9.63%
System Energy [Member] | Grand Gulf [Member]
Regulatory Assets [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage																																																																				11.50%
Entergy Holdings Company LLC [Member]
Regulatory Assets [Line Items]
Class preferred, non-voting, membership interest units | shares																																																	2,935,152.69
Annual distribution rate																																																	7.50%
Liquidation price per unit | $ / unit																																																	100
Net worth required under terms of membership interest																																																	$ 1,750,000,000
Minimum [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Intervenor recommended disallowance of revenue requirement																					$ 300,000
Minimum [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Recommended adjustment to earned return on equity																																														8.37%
Minimum [Member] | System Energy [Member] | First Refund Period [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																10.10%			10.10%																																								8.57%
Minimum [Member] | System Energy [Member] | Second refund period [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																						8.28%													10.32%
Maximum [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																												9.35%
Public Utilities, Approved Equity Capital Structure, Percentage																												50.00%
public utilities proposed customer credits																			400
Maximum [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Intervenor recommended disallowance of revenue requirement																				$ 4,100,000
Maximum [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Recommended adjustment to earned return on equity																																														8.67%
Percent Equity in Proposed Common Equity Ratio																														37.00%
Percent Debt in Proposed Common Equity Ratio																														63.00%
LPSC Argued Equity Capital Structure, Percentage																														49.00%
APSC and MPSC Argued Equity Capital Structure, Percentage																														35.98%
APSC and MPSC Alternative Argued Equity Capital Structure, Percentage																														46.75%
FERC Percent Equity in Proposed Common Equity Ratio																													46.74%
FERC Percent Debt in Proposed Common Equity Ratio																													53.26%
ALJ Recommended Equity Capital Structure, Percentage													48.15%
Maximum [Member] | System Energy [Member] | First Refund Period [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																			10.70%																																								9.52%
Maximum [Member] | System Energy [Member] | Second refund period [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																						9.11%													10.69%
Montgomery County Power Station | Entergy Texas [Member]
Regulatory Assets [Line Items]
Property, Plant and Equipment, Useful Life															38 years
Attorney General Litigation Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					20,500,000										$ 25,300,000																																														20,500,000		25,300,000					$ 20,500,000		25,300,000
Attorney General Litigation Costs [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					20,500,000										25,300,000																																														20,500,000		25,300,000					20,500,000		25,300,000
Opportunity Sales [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					131,800,000										131,800,000																																														131,800,000		131,800,000					131,800,000		131,800,000
Opportunity Sales [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					131,800,000										131,800,000																					116,000,000																									131,800,000		131,800,000					131,800,000		131,800,000			116,000,000
Nuclear Generation Development Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					6,800,000										14,200,000																																														6,800,000		14,200,000					6,800,000		14,200,000
Nuclear Generation Development Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					6,700,000										14,000,000																																														6,700,000		14,000,000					6,700,000		14,000,000
Asset Retirement Obligation Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					935,500,000										1,018,900,000																																														935,500,000		1,018,900,000					935,500,000		1,018,900,000
Asset Retirement Obligation Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					286,600,000										299,000,000																																														286,600,000		299,000,000					286,600,000		299,000,000
Asset Retirement Obligation Costs [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					8,400,000										7,900,000																																														8,400,000		7,900,000					8,400,000		7,900,000
Asset Retirement Obligation Costs [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					5,400,000										5,200,000																																														5,400,000		5,200,000					5,400,000		5,200,000
Asset Retirement Obligation Costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					489,200,000										479,300,000																																														489,200,000		479,300,000					489,200,000		479,300,000
Asset Retirement Obligation Costs [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					144,400,000										226,300,000																																														144,400,000		226,300,000					144,400,000		226,300,000
New Orleans Power Station deferral | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					4,000,000																																																								4,000,000							4,000,000
Provision For Storm Damages, Including Hurricane Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					993,600,000										379,200,000																																														993,600,000		379,200,000					993,600,000		379,200,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					1,100,000,000																																																								1,100,000,000							1,100,000,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					773,600,000										94,000,000																																														773,600,000		94,000,000					773,600,000		94,000,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Louisiana [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					1,000,000,000																																																								1,000,000,000							1,000,000,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					31,200,000										55,200,000																																														31,200,000		55,200,000					31,200,000		55,200,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy New Orleans [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					80,000,000																																																								80,000,000							80,000,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					143,100,000										187,300,000																																														143,100,000		187,300,000					143,100,000		187,300,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent					39,300,000										42,700,000																																														39,300,000		42,700,000					39,300,000		42,700,000
Subsequent Event [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																																																													9.50%
Distribution recovery mechanism - amount per year																																																																													$ 225,000,000
Formula rate plan revenue increase limit - exclusive of riders																																																																												$ 70,000,000
Deferral of expenditures on vegetation management																																																																												7,000,000
Storm Reserve Escrow Account				$ 290,000,000
Aggregate principal amount of system restoration bonds authorization requested				3,186,000,000
Distribution recovery mechanism - amount per year																																																																													$ 225,000,000
Formula rate plan revenue increase limit - exclusive of riders																																																																												70,000,000
Deferral of expenditures on vegetation management																																																																												$ 7,000,000
Storm Reserve Escrow Account				290,000,000
Aggregate principal amount of system restoration bonds authorization requested				3,186,000,000
Subsequent Event [Member] | Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs				2,100,000,000
Storm carrying costs				51,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs				2,100,000,000
Subsequent Event [Member] | Entergy Louisiana [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Deferred Storm and Property Reserve Deficiency, Noncurrent				1,000,000,000
Subsequent Event [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost - Net Asset																																																																																$ 100,000,000
Subsequent Event [Member] | Entergy New Orleans [Member] | Hurricane Ida
Regulatory Assets [Line Items]
Replenishment amount for storm reserve spending				$ 150,000,000
Subsequent Event [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																																																		9.65%
Energy Cost Recovery Rider Rate Per kWh																																																																			$ 0.00959
Subsequent Event [Member] | Minimum [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																																																													9.00%
Subsequent Event [Member] | Maximum [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																																																													10.00%
Vidalia Purchased Power Agreement [Member]
Regulatory Assets [Line Items]
Regulatory Liability, Noncurrent					106,200,000										115,700,000																																														106,200,000		115,700,000					106,200,000		115,700,000
Increase (Decrease) in Regulatory Liabilities																																												$ (30,500,000)
Vidalia Purchased Power Agreement [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Liability, Noncurrent					106,200,000										115,700,000																																														106,200,000		115,700,000					106,200,000		115,700,000
Louisiana Act 55 Financing Obligation [Member]
Regulatory Assets [Line Items]
Regulatory Liability, Noncurrent					127,400,000										144,300,000																																														127,400,000		144,300,000					127,400,000		144,300,000
Increase (Decrease) in Regulatory Liabilities																																												$ (25,000,000)
Louisiana Act 55 Financing Obligation [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Liability, Noncurrent					127,400,000										144,300,000																																														127,400,000		144,300,000					127,400,000		144,300,000
Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
Regulatory Liability, Noncurrent					0										43,500,000																																														0		43,500,000					0		43,500,000
Revenue Subject to Refund [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return																																				9,300,000																																					9,300,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return																																$ 900,000		800,000																																												$ 800,000
Revenue Subject to Refund [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return																																				$ 35,100,000																																					$ 35,100,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return																																$ 11,500,000
Regulatory Liability, Noncurrent					$ 0										43,500,000																																														0		43,500,000					$ 0		$ 43,500,000
Electricity [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																						10.50%
Return on equity including performance adder provision																																						10.75%
Public Utilities, Requested Rate Increase (Decrease), Amount									$ 40,000,000															$ 42,000,000		42,000,000		$ 36,000,000
Rider reductions included in decreased rates																								29,000,000		29,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount	34,900,000								5,200,000
Public Utilities, Interim Rate Increase (Decrease), Amount						10,000,000
Customer Refund Liability, Current	17,400,000
Natural Gas [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																						10.75%
Public Utilities, Requested Rate Increase (Decrease), Amount									18,800,000															$ 3,000,000		$ 3,000,000		$ 3,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 14,600,000								300,000
Public Utilities, Interim Rate Increase (Decrease), Amount						4,500,000
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount						66,100,000											51,000,000													$ 19,400,000
Revenue increase resulting from incremental revenue																														16,700,000																											$ 31,600,000								$ 15,100,000
Public Utilities, Approved Rate Increase (Decrease), Amount																														$ 2,700,000	$ 2,700,000
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount								$ 40,200,000									26,300,000						$ 23,600,000											$ 3,200,000
Revenue increase resulting from incremental revenue																	16,300,000						$ 20,400,000																																							$ 6,800,000		$ 13,900,000
2020 Formula Rate Plan
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount																																																																								$ 7,300,000
Public Utilities Temporary Rate Increase Amount																						$ 24,300,000
2020 Formula Rate Plan | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Earned return on common equity								8.45%		8.45%
Public Utilities, Requested Rate Increase (Decrease), Amount								$ 14,200,000		$ 63,000,000
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount								64,900,000		50,700,000
2020 Formula Rate Plan | Entergy Louisiana [Member] | Legacy Entergy Louisiana
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount								32,800,000		27,000,000
2020 Formula Rate Plan | Entergy Louisiana [Member] | Legacy Entergy Gulf States Louisiana
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount								$ 32,100,000		$ 23,700,000
2020 Formula Rate Plan | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Public Utilities, Approved Return on Equity, Percentage																																																																								6.75%
Public Utilities, Requested Return on Equity, Percentage																																																																						6.51%
Public Utilities, Requested Rate Increase (Decrease), Amount																																																																						$ 24,600,000
Cap on 2019 retail revenues																																																																								2.00%
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount																																																																						23,800,000
2020 Formula Rate Plan | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																																																				8.22%				9.07%
Public Utilities, Requested Rate Increase (Decrease), Amount																			$ 88,200,000
Provision for Rate Refund															43,500,000																																																$ 43,500,000							$ 43,500,000
Reduced proposed revenue increase resulting from new methodology															43,500,000
Projected Revenue Deficiency																	44,500,000																																												$ 39,800,000							$ 64,300,000				$ 23,900,000
Generation Cost Recovery Rider | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount						88,300,000									$ 86,000,000		$ 91,000,000
Unit Power Sales Agreement [Member] | System Energy [Member]
Regulatory Assets [Line Items]
New Orleans City Council Witness Recommended Refund																																																																															$ 98,800,000
New Orleans City Council Recommended Hypothetical Equity Ratio Prospectively					48.15%																																																								48.15%							48.15%
2021 Formula Rate Plan | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Rate Increase Included in Formula Rate Plan													$ 44,300,000
Public Utilities, Requested Return on Equity, Percentage										6.12%			6.69%
Public Utilities, Requested Rate Increase (Decrease), Amount										$ 48,200,000			$ 95,400,000
Demand side management costs													3,900,000
Formula rate plan revenue increase including demand side management costs													48,200,000
Interim increase in formula rate plan revenues										17,500,000			16,800,000
Interim rate adjustment										1,700,000			1,700,000
Total interim rate adjustments													18,500,000
Interim increase in formula rate plan revenues due to adjustments													$ 22,100,000
Cap on 2020 retail revenues													2.00%
Formula rate plan increase related to COVID-19 non-bad debt expense										3,700,000
Other Regulatory Charges Credits Net										$ 19,900,000
2021 Formula Rate Plan | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																																																						7.92%
Public Utilities, Requested Rate Increase (Decrease), Amount						$ 82,200,000			$ 108,700,000
Projected Revenue Deficiency																																																																				$ 19,400,000
2021 Formula Rate Plan | Maximum [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage													4.00%
2021 Formula Rate Plan | Subsequent Event [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																																																																		7.65%
Projected Revenue Deficiency																																																																		$ 89,200,000
Projected Increase in Revenue Requirement																																																																		$ 62,800,000

Rate And Regulatory Matters (De

Rate And Regulatory Matters (Details Of Other Regulatory Assets Included In Entergy Corporation And Subsidiaries) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2018
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	$ 6,613,256	$ 6,076,549
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	1,689,678	1,832,384
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	2,776,666	1,726,066
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	462,432	467,341
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	248,617	266,790
Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	421,333	524,713
System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	395,546	538,963
Asset Retirement Obligation [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	935,500	1,018,900
Asset Retirement Obligation [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	489,200	479,300
Asset Retirement Obligation [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	286,600	299,000
Asset Retirement Obligation [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	8,400	7,900
Asset Retirement Obligation [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	5,400	5,200
Asset Retirement Obligation [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	144,400	226,300
Pension And Post Retirement Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	2,327,700	3,027,500
Pension And Post Retirement Costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	640,000	831,500
Pension And Post Retirement Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	592,700	799,400
Pension And Post Retirement Costs [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	175,400	242,700
Pension And Post Retirement Costs [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	44,900	75,700
Pension And Post Retirement Costs [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	96,000	140,100
Pension And Post Retirement Costs [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	160,300	217,800
Provision For Storm Damages, Including Hurricane Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	993,600	379,200
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	39,300	42,700
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	773,600	94,000
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	31,200	55,200
Provision For Storm Damages, Including Hurricane Costs [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	143,100	187,300
Removal Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	1,488,800	893,800
Removal Costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	224,300	212,600
Regulatory Assets	224,300	212,600
Removal Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	848,200	302,500
Regulatory Assets	848,200	302,500
Removal Costs [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	136,800	107,300
Regulatory Assets	136,800	107,300
Removal Costs [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	91,700	63,200
Regulatory Assets	91,700	63,200
Removal Costs [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	98,100	115,300
Regulatory Assets	98,100	115,300
Removal Costs [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	89,700	92,900
Regulatory Assets	89,700	92,900
Attorney General Litigation Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	20,500	25,300
Attorney General Litigation Costs [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	20,500	25,300
Nuclear Generation Development Costs [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	6,800	14,200
Nuclear Generation Development Costs [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	6,700	14,000
Neches and Sabine Costs [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	16,400	18,800
Regulatory Clause Revenues, under-recovered [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	66,100	66,000
Regulatory Clause Revenues, under-recovered [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	1,000	12,600
Regulatory Clause Revenues, under-recovered [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	48,100	44,300
Unamortized Loss on Reacquired Debt [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	74,700	79,200
Unamortized Loss on Reacquired Debt [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	23,100	24,700
Unamortized Loss on Reacquired Debt [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	26,900	26,600
Unamortized Loss on Reacquired Debt [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	12,200	13,500
Unamortized Loss on Reacquired Debt [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	1,600	1,900
Unamortized Loss on Reacquired Debt [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	9,800	10,500
Unamortized Loss on Reacquired Debt [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	1,100	2,000
ANO Fukushima and Flood Barrier costs [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	7,300	9,100
Opportunity Sales [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	131,800	131,800
Opportunity Sales [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	131,800	131,800	$ 116,000
Retired electric meters [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	43,400	46,900
Retired electric meters [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	91,700	96,400
Retired electric meters [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	23,700	26,000
Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	123,100	125,900
Other Regulatory Assets (Liabilities) [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	17,900	21,200
Other Regulatory Assets (Liabilities) [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	39,000	40,000
Other Regulatory Assets (Liabilities) [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	13,200	5,100
Other Regulatory Assets (Liabilities) [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	36,800	29,600
Other Regulatory Assets (Liabilities) [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	7,900	10,000
Retired electric and gas meters [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	179,400	192,100
Retired electric and gas meters [Member] | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	19,600	21,700
Deferred COVID-19 costs
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	133,100	105,700
Deferred COVID-19 costs | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	32,600	10,500
Deferred COVID-19 costs | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	56,300	48,800
Deferred COVID-19 costs | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	15,000	19,200
Deferred COVID-19 costs | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	17,400	14,300
Deferred COVID-19 costs | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	11,700	12,900
New Orleans Power Station deferral | Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	4,000
Pension & post retirement benefits expense deferral | Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	14,600	3,800
Qualified Pension Settlement Cost Deferral
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	113,200	16,900
Qualified Pension Settlement Cost Deferral | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	39,800	9,500
Qualified Pension Settlement Cost Deferral | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	55,000	5,400
Qualified Pension Settlement Cost Deferral | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	13,800	2,000
Formula rate plan historical year rate adjustment [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	19,000	0
Formula rate plan historical year rate adjustment [Member] | Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Regulatory Assets, Noncurrent	$ 19,000	$ 0

Rate And Regulatory Matters Rat

Rate And Regulatory Matters Rate and Regulatory Matters (Details of Other Regulatory Liabilities Included in Entergy Corporation and Subsidiaries) (Details) - USD ($) $ in Thousands	Jan. 01, 2018	Dec. 31, 2017	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%					35.00%	35.00%
Regulatory Liability, Noncurrent			$ 2,643,845	$ 2,323,851
Increase (Decrease) in Regulatory Liabilities			(43,631)	(238,669)	$ 14,781
Unrealized Gain on Nuclear Decommissioning Trust Funds [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			1,993,300	1,694,100
Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			45,500	29,700
Vidalia Purchased Power Agreement [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			106,200	115,700
Increase (Decrease) in Regulatory Liabilities		$ 30,500
Entergy Arkansas’s Accumulated Accelerated Grand Gulf Amortization [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			44,400	44,400
Revenue Subject to Refund [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			0	43,500
Internal Restructuring Guaranteed Credits to Customers [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			19,800	26,400
Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			83,700	53,500
Grand Gulf Sale Leaseback [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			55,600	55,600
Business Combination Guaranteed Customer Benefits [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			16,000	21,500
Grand Gulf Over-Recovery [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			126,500	75,100
Louisiana Act 55 Financing Obligation [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			127,400	144,300
Increase (Decrease) in Regulatory Liabilities		$ 25,000
Advanced Metering System Surcharge [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			7,300	20,100
Deferred Tax Equity Partnership Earnings
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			18,100	$ 0
Entergy Louisiana [Member]
Regulatory Liabilities [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent				21.00%
Regulatory Liability, Noncurrent			1,042,597	$ 918,293
Increase (Decrease) in Regulatory Liabilities			16,478	(71,698)	35,881
Entergy Louisiana [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			692,200	567,700
Entergy Louisiana [Member] | Asset Retirement Obligation Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			45,500	29,700
Entergy Louisiana [Member] | Vidalia Purchased Power Agreement [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			106,200	115,700
Entergy Louisiana [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			13,200	3,400
Entergy Louisiana [Member] | Business Combination Guaranteed Customer Benefits [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			16,000	21,500
Entergy Louisiana [Member] | Grand Gulf Over-Recovery [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			30,700	36,000
Entergy Louisiana [Member] | Louisiana Act 55 Financing Obligation [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			127,400	144,300
Entergy Louisiana [Member] | Derivative Instruments & Hedging Activities
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			11,400	0
Entergy Arkansas [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			743,314	686,872
Increase (Decrease) in Regulatory Liabilities			(21,066)	(106,878)	(39,293)
Entergy Arkansas [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			685,400	597,400
Entergy Arkansas [Member] | Revenue Subject to Refund [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			0	43,500
Entergy Arkansas [Member] | Internal Restructuring Guaranteed Credits to Customers [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			19,800	26,400
Entergy Arkansas [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			1,100	0
Entergy Arkansas [Member] | Grand Gulf Over-Recovery [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			18,900	19,600
Entergy Arkansas [Member] | Deferred Tax Equity Partnership Earnings
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			18,100	0
Entergy Mississippi [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			49,313	15,828
Increase (Decrease) in Regulatory Liabilities			(21,930)	18,672	21,524
Entergy Mississippi [Member] | Grand Gulf Over-Recovery [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			15,100	1,000
Entergy Mississippi [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			0	600
Entergy Mississippi [Member] | Grand Gulf Over-Recovery [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			34,200	14,200
Entergy New Orleans [Member]
Regulatory Liabilities [Line Items]
Increase (Decrease) in Regulatory Liabilities			(4,985)	4,728	22,105
Entergy Texas [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			37,060	32,297
Increase (Decrease) in Regulatory Liabilities			28,747	57,477	105,517
Entergy Texas [Member] | Transition to Competition Costs [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			0	3,200
Entergy Texas [Member] | Other Regulatory Assets (Liabilities) [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			4,300	2,500
Entergy Texas [Member] | Income Tax Rate Change [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			2,700	6,500
Entergy Texas [Member] | Advanced Metering System Surcharge [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			7,300	20,100
Entergy Texas [Member] | Retail refunds
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			22,800	0
System Energy [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			744,944	665,396
Increase (Decrease) in Regulatory Liabilities			(40,884)	(140,965)	$ (130,949)
System Energy [Member] | Unrealized Gain on Nuclear Decommissioning Trust Funds [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			615,700	529,000
System Energy [Member] | Entergy Arkansas’s Accumulated Accelerated Grand Gulf Amortization [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			44,400	44,400
System Energy [Member] | Entergy Mississippi’s accumulated accelerated Grand Gulf amortization [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			3,600	10,700
System Energy [Member] | Grand Gulf Sale Leaseback [Member]
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			55,600	55,600
System Energy [Member] | Grand Gulf Sale Leaseback accumulated deferred income taxes
Regulatory Liabilities [Line Items]
Regulatory Liability, Noncurrent			$ 25,600	$ 25,700

Rate And Regulatory Matters (Fu

Rate And Regulatory Matters (Fuel And Purchased Power Cost Recovery) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Deferred Fuel Cost Non Current	$ 240,953	$ 240,422
Entergy Arkansas [Member]
Deferred Fuel Cost - Net Asset	177,600	15,200
Deferred Fuel Cost Non Current	68,751	68,220
Entergy Louisiana [Member]
Deferred Fuel Cost - Net Asset	213,500	170,400
Deferred Fuel Cost Non Current	168,122	168,122
Entergy Mississippi [Member]
Deferred Fuel Cost - Net Asset	121,900
Deferred Fuel Cost - Net Liability		(14,700)
Entergy New Orleans [Member]
Deferred Fuel Cost - Net Asset		6,200
Deferred Fuel Cost - Net Liability	(3,500)
Deferred Fuel Cost Non Current	4,080	4,080
Entergy Texas [Member]
Deferred Fuel Cost - Net Asset	$ 48,300
Deferred Fuel Cost - Net Liability		$ (85,400)

Rate And Regulatory Matters R_2

Rate And Regulatory Matters Rate and Regulatory Matters (Opportunity Sales Proceeding) (Details) $ in Millions	1 Months Ended
	Dec. 31, 2018USD ($)
Entergy Arkansas [Member]
Payments to utility operating companies pursuant to Opportunity Sales Proceeding	$ 135
Entergy Arkansas [Member] | Principal
Payments to utility operating companies pursuant to Opportunity Sales Proceeding	68
Entergy Arkansas [Member] | Interest Expense
Payments to utility operating companies pursuant to Opportunity Sales Proceeding	67
Entergy Louisiana [Member]
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(59)
Entergy Louisiana [Member] | Principal
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(30)
Entergy Louisiana [Member] | Interest Expense
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(29)
Entergy Mississippi [Member]
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(36)
Entergy Mississippi [Member] | Principal
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(18)
Entergy Mississippi [Member] | Interest Expense
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(18)
Entergy New Orleans [Member]
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(7)
Entergy New Orleans [Member] | Principal
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(3)
Entergy New Orleans [Member] | Interest Expense
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(4)
Entergy Texas [Member]
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(33)
Entergy Texas [Member] | Principal
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	(17)
Entergy Texas [Member] | Interest Expense
Receipts from utility operating companies pursuant to Opportunity Sales Proceeding	$ (16)

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 01, 2018	Oct. 31, 2015	Aug. 31, 2008	Jul. 31, 2008	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2016	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2021	Nov. 30, 2019	Jan. 01, 2019
Income Taxes [Line Items]
Valuation allowance on the deferred tax assets related to state net operating loss carryovers						$ 329,000										$ 325,000	$ 329,000
Unrecognized tax benefits if recognized, would lower the effective income tax rates						2,208,000		$ 2,421,000								2,256,000	2,208,000	$ 2,421,000
Remaining balances of unrecognized tax benefits, effective income tax rates						3,491,000		4,962,000								3,504,000	3,491,000	4,962,000
Accrued income tax interest and penalties						44,000		48,000								52,000	44,000	48,000
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense																8,000		4,000
Deferred Income Taxes and Tax Credits																248,719	(131,114)	193,950
Deferred Tax Assets, Valuation Allowance						328,581										325,239	328,581
Regulatory Liability, Noncurrent						2,323,851										2,643,845	2,323,851
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%																		35.00%	35.00%
Regulatory Liability For Income Taxes - Current and Non Current						1,600,000										1,300,000	1,600,000
Deferred tax asset operating loss carryforward EUHC re-consolidation													$ 41,000
Net operating loss carryforwards						1,580,109										2,868,424	1,580,109
Deferred Tax Assets, Net of Valuation Allowance						4,214,739										4,963,459	4,214,739
Increase (Reduction) in income tax resulting from Entergy Wholesale Commodities restructuring																0	9,223	173,725
Regulatory Liability For Income Taxes Net						1,521,757										1,255,692	1,521,757
Preferred Stock, Value, Issued						0										0	0
Discontinued Operation, Tax Effect of Discontinued Operation									$ 29,000
Permanent difference and income tax benefit		$ 334,000
Reduction in deferred income tax expense																	230,000
Increase in deferred income tax expense																	61,000
Miscellaneous tax benefits																	13,000
Adjustable taxable income limitation	30.00%																							50.00%
Percent of tax group's consolidated assets that consist of regulated utility property																						90.00%
CARES Act Deferred Tax Expense																	64,000
CARES Act annual payroll tax installment due resulting from deferred tax payments																32,000
Reduction in unrecognized tax benefits due to decommissioning liability in COGS																1,500,000
Permanent tax reduction due to stock compensation accounting rules							$ 24,700
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(4,000)
Deferred Income Tax Assets, Net						76,289										54,186	76,289
Deferred Income Tax Liabilities, Net						4,361,772										$ 4,706,797	4,361,772
Limitation on net operating loss carryforwards resulting from Federal CARES Act																80.00%
State of Louisiana Enacted Tax Legislation 2021
Income Taxes [Line Items]
Deferred Income Tax Assets, Net																$ 27,000
Entergy Wholesale Commodities [Member]
Income Taxes [Line Items]
Deferred Income Taxes and Tax Credits																	105,000
Increase in deferred income tax expense																	105,000
Entergy Arkansas [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						259,300		203,300								262,100	259,300	203,300
Accrued income tax interest and penalties						2,300		3,100								2,700	2,300	3,100
Deferred Income Taxes and Tax Credits																100,459	87,019	94,368
Regulatory Liability, Noncurrent						686,872										743,314	686,872
Regulatory Liability For Income Taxes - Current and Non Current						21,000										11,000	21,000
Net operating loss carryforwards						119,555										275,054	119,555
Deferred Tax Assets, Net of Valuation Allowance						554,255										740,723	554,255
Change in accounting method for tax purposes, effect of change on taxable income										$ 1,800,000
Accrued deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements										2,100,000									$ 2,100,000
Regulatory Liability For Income Taxes Net						467,031										$ 431,655	467,031
State Effective Income Tax Rate, Percent												6.50%				6.20%
Permanent tax reduction due to stock compensation accounting rules							4,800
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(800)
Deferred Income Tax Liabilities, Net						1,286,123										$ 1,416,201	1,286,123
Entergy Louisiana [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						63,800		556,300								66,300	63,800	556,300
Accrued income tax interest and penalties						3,400		14,200								3,700	3,400	14,200
Deferred Income Taxes and Tax Credits																175,700	(356,256)	196,533
Regulatory Liability, Noncurrent						918,293										1,042,597	$ 918,293
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent																	21.00%
Net operating loss carryforwards						363,806										1,228,547	$ 363,806
Deferred Tax Assets, Net of Valuation Allowance						700,307										2,013,578	700,307
Change in accounting method for tax purposes, effect of change on taxable income											$ 2,200,000
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements																					$ 2,200,000
Regulatory Liability For Income Taxes Net						447,628										313,693	447,628
Reduction in deferred income tax expense																	383,000
Reduction to income tax expense due to method of accounting																	31,000
Regulatory charge due to prior regulatory settlement - gross																	33,000
Regulatory charge due to prior regulatory settlement - net of tax																	24,000
Increase (Reduction) in income tax resulting from Act 55 financing settlement					$ 32,000		32,000
Reduction of income tax expense due reversal of UTPs					58,000		58,000
Regulatory charge due to LPSC Act 55 Financing Order - Gross					29,000		29,000
Regulatory charge due to LPSC Act 55 Financing Order - Net of Tax					$ 21,000		21,000
Deferred tax liability due to decommissioning liability in COGS																60,000
Decommissioning liability in COGS																221,000
Reduction in unrecognized tax benefits due to decommissioning liability in COGS																1,100,000
Permanent tax reduction due to stock compensation accounting rules							8,600
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(10,800)	(3,700)
Deferred Income Tax Liabilities, Net						2,138,522										$ 2,433,854	2,138,522
Entergy Louisiana [Member] | State of Louisiana Enacted Tax Legislation 2021
Income Taxes [Line Items]
State Effective Income Tax Rate, Percent																8.00%
Reduction in deferred income tax expense																$ 6,000
Increase in state tax rate																0.85%
Deferred Income Tax Liabilities, Net																$ 77,000
Entergy Mississippi [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						50,700		1,900								51,700	50,700	1,900
Accrued income tax interest and penalties						1,900		1,700								2,400	1,900	1,700
Deferred Income Taxes and Tax Credits																64,868	36,827	32,547
Regulatory Liability, Noncurrent						15,828										49,313	15,828
Net operating loss carryforwards						54,262										166,008	54,262
Deferred Tax Assets, Net of Valuation Allowance						131,887										240,369	131,887
Accrued deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements										$ 1,900,000									$ 1,900,000
Regulatory Liability For Income Taxes Net						224,000										212,445	224,000
Permanent tax reduction due to stock compensation accounting rules							2,700
Deferred Income Tax Liabilities, Net						646,674										720,097	646,674
Entergy New Orleans [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						203,500		242,700								228,600	203,500	242,700
Accrued income tax interest and penalties						3,900		4,700								5,200	3,900	4,700
Deferred Income Taxes and Tax Credits																12,573	3,938	21,350
Net operating loss carryforwards						26,564										105,549	26,564
Deferred Tax Assets, Net of Valuation Allowance						88,881										155,805	88,881
Reduction to income tax expense																	8,000
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements																				$ 1,100,000
Regulatory Liability For Income Taxes Net						55,675										40,589	55,675
Permanent tax reduction due to stock compensation accounting rules							1,500
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(800)
Deferred Income Tax Liabilities, Net						338,714										365,384	338,714
Entergy New Orleans [Member] | State of Louisiana Enacted Tax Legislation 2021
Income Taxes [Line Items]
Reduction in deferred income tax expense																2,000
Deferred Income Tax Liabilities, Net																8,000
Entergy Texas [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						6,100		5,700								2,600	6,100	5,700
Accrued income tax interest and penalties						900		1,100								1,100	900	1,100
Deferred Income Taxes and Tax Credits																48,813	36,033	20,143
Regulatory Liability, Noncurrent						32,297										37,060	32,297
Net operating loss carryforwards						53,052										81	53,052
Deferred Tax Assets, Net of Valuation Allowance						60,543										58,450	60,543
Deductible temporary difference related to election to mark-to-market certain power purchase and sales agreements																	2,500,000
Regulatory Liability For Income Taxes Net						175,594										144,145	175,594
Permanent tax reduction due to stock compensation accounting rules							2,700
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(200)
Deferred Income Tax Liabilities, Net						639,422										692,496	639,422
System Energy [Member]
Income Taxes [Line Items]
Unrecognized tax benefits if recognized, would lower the effective income tax rates						500		0								1,700	500	0
Accrued income tax interest and penalties						11,900		14,500								12,100	11,900	14,500
Deferred Income Taxes and Tax Credits																11,191	(455,732)	$ 95
Regulatory Liability, Noncurrent						665,396										744,944	665,396
Net operating loss carryforwards						0										0	0
Deferred Tax Assets, Net of Valuation Allowance						311,353										347,153	311,353
Change in accounting method for tax purposes, effect of change on taxable income											$ 1,200,000
Regulatory Liability For Income Taxes Net						151,829										113,165	151,829
Deferred tax liability due to decommissioning liability in COGS																26,000
Decommissioning liability in COGS																102,000
Federal and state taxes payable due to decommissioning liability in COGS																402,000
Reduction in unrecognized tax benefits due to decommissioning liability in COGS																461,000
Permanent tax reduction due to stock compensation accounting rules							$ 1,300
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense																	(2,600)
Deferred Income Tax Liabilities, Net						359,835										382,931	359,835
Entergy Wholesale Commodities [Member]
Income Taxes [Line Items]
Increase (Reduction) in income tax resulting from Entergy Wholesale Commodities restructuring						9,200		19,000
Reduction to income tax expense								174,000
Change in accounting method for tax purposes, effect of change on taxable income								$ 18,000
Reduction in unrecognized tax benefits due to decommissioning liability in COGS																							$ 156,000
Hurricane Rita [Member] | Entergy Gulf States Louisiana [Member]
Income Taxes [Line Items]
Proceeds from LURC			$ 274,700
Proceed from loan by LCDA to corporation LURC			$ 274,700
Hurricane Rita [Member] | Entergy Louisiana [Member]
Income Taxes [Line Items]
Proceeds from LURC				$ 679,000
Proceed from loan by LCDA to corporation LURC				$ 679,000
Subsequent Event [Member] | Entergy Arkansas [Member]
Income Taxes [Line Items]
State Effective Income Tax Rate, Percent														5.70%	5.90%
Subsequent Event [Member] | Entergy Louisiana [Member] | State of Louisiana Enacted Tax Legislation 2021
Income Taxes [Line Items]
State Effective Income Tax Rate, Percent															7.50%
Internal Restructuring Guaranteed Credits to Customers [Member]
Income Taxes [Line Items]
Regulatory Liability, Noncurrent						26,400										19,800	26,400
Internal Restructuring Guaranteed Credits to Customers [Member] | Entergy Arkansas [Member]
Income Taxes [Line Items]
Regulatory Liability, Noncurrent						$ 26,400										$ 19,800	$ 26,400
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Income Taxes [Line Items]
Preferred Stock, Value, Issued												$ 35,000	$ 35,000
Preferred Stock, Dividend Rate, Percentage													5.375%
Preferred Stock, Liquidation Preference Per Share												$ 25	$ 25

Income Taxes (Schedule Of Incom

Income Taxes (Schedule Of Income Tax Expenses From Continuing Operations) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Federal	$ (5,003)	$ 5,807	$ (14,416)
State	(8,995)	57,939	6,535
Total	(13,998)	63,746	(7,881)
Deferred and non-current -- net	205,891	(190,635)	(155,956)
Investment tax credit adjustments - net	(519)		(5,988)
Deferred Other Tax Expense (Benefit)		(5,383)
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Entergy Arkansas [Member]
Federal	(20,285)	(44,627)	(14,549)
State	529	(2,563)	(714)
Total	(19,756)	(47,190)	(15,263)
Deferred and non-current -- net	96,180	96,195	(30,278)
Investment tax credit adjustments - net	(1,229)	(1,228)	(1,228)
Income Tax Expense (Benefit)	75,195	47,777	(46,769)
Entergy Louisiana [Member]
Federal	(24,053)	62,728	(20,173)
State	2,459	4,457	(735)
Total	(21,594)	67,185	(20,908)
Deferred and non-current -- net	146,786	(444,647)	147,453
Investment tax credit adjustments - net	(4,783)	(4,862)	(4,922)
Income Tax Expense (Benefit)	120,409	(382,324)	121,623
Entergy Mississippi [Member]
Federal	(5,868)	(14,580)	(8,939)
State	(11,506)	(1,316)	5,823
Total	(17,374)	(15,896)	(3,116)
Deferred and non-current -- net	60,861	43,640	34,579
Investment tax credit adjustments - net		(554)	(597)
Deferred Other Tax Expense (Benefit)	(1,836)
Income Tax Expense (Benefit)	45,323	27,190	30,866
Entergy New Orleans [Member]
Federal	(6,724)	293	(5,822)
State	(413)	(303)	1,856
Total	(7,137)	(10)	(3,966)
Deferred and non-current -- net	12,870	(18,153)	4,248
Investment tax credit adjustments - net			(96)
Deferred Other Tax Expense (Benefit)	(203)	(13,956)
Income Tax Expense (Benefit)	5,936	(4,207)	186
Entergy Texas [Member]
Federal	(189)	(5,603)	16,035
State	1,261	2,658	663
Total	1,072	(2,945)	16,698
Deferred and non-current -- net	25,087	6,619	(69,963)
Investment tax credit adjustments - net	(633)	(632)	(631)
Income Tax Expense (Benefit)	25,526	3,042	(53,896)
System Energy [Member]
Federal	29,416	372,206	16,256
State	(10,258)	55,551	(2,831)
Total	19,158	427,757	13,425
Deferred and non-current -- net	(25,229)	(405,928)	422
Investment tax credit adjustments - net		(1,286)
Deferred Other Tax Expense (Benefit)	4,094		(1,502)
Income Tax Expense (Benefit)	$ (1,977)	$ 20,543	$ 15,349

Income Taxes (Schedule Of Statu

Income Taxes (Schedule Of Statutory Income Tax Rate To Income Before Taxes) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Utility Restructuring	$ (27,108)	$ 0	$ 0
IRS Audit Adjustment	0	(301,041)	0
Net Income (Loss) Attributable to Parent	1,118,492	1,388,334	1,241,226
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	227	18,319	17,018
Consolidated net income	1,118,719	1,406,653	1,258,244
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	1,310,093	1,285,147	1,088,419
Computed at statutory rate (35%)	275,120	269,881	228,568
State income taxes net of federal income tax effect	79,273	60,087	61,791
Regulatory differences - utility plant items	(57,556)	(53,229)	(45,336)
Equity component of AFUDC	(14,799)	(25,080)	(30,444)
Amortization of investment tax credits	(7,695)	(8,386)	(8,093)
Flow-through / permanent differences	(5,585)	11,099	(2,059)
Amortization of Excess ADIT	(66,478)	(59,629)	(205,614)
Income Tax Reconciliation Provision For Uncertain Tax Positions	16,533	15,208	7,332
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	(2,600)	0	59,345
Other - net	$ 2,269	$ 4,398	$ (1,062)
Effective Income Tax Rate	14.60%	(9.50%)	(15.60%)
Increase (Reduction) in income tax resulting from Entergy Wholesale Commodities restructuring	$ 0	$ (9,223)	$ (173,725)
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount	0	25,591	0
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Charitable Contributions, Amount	0	0	19,101
Net operating loss recognition	0	0	(41,427)
Entergy Arkansas [Member]
Utility Restructuring	398
IRS Audit Adjustment		6,351
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	(18,092)	0	0
Consolidated net income	298,484	245,232	262,964
Income Tax Expense (Benefit)	75,195	47,777	(46,769)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	373,679	293,009	216,195
Income before income taxes	373,679	293,009	216,195
Computed at statutory rate (35%)	78,473	61,532	45,401
State income taxes net of federal income tax effect	19,633	16,256	15,954
Regulatory differences - utility plant items	(16,078)	(8,034)	(10,627)
Equity component of AFUDC	(3,207)	(3,154)	(3,255)
Amortization of investment tax credits	(1,201)	(1,201)	(1,201)
Flow-through / permanent differences	(814)	(2,219)	696
Amortization of Excess ADIT	(5,845)	(6,011)	90,921
Income Tax Reconciliation Provision For Uncertain Tax Positions	353	1,200	(3,517)
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	(2,766)
Other - net	$ 717	$ 711	$ 701
Effective Income Tax Rate	20.10%	16.30%	(21.60%)
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (4,952)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ 0	0	$ 0
Entergy Louisiana [Member]
Utility Restructuring	(6,126)
IRS Audit Adjustment		471,702
Consolidated net income	653,984	1,082,352	691,537
Income Tax Expense (Benefit)	120,409	(382,324)	121,623
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	774,393	700,028	813,160
Income before income taxes	774,393	700,028	813,160
Computed at statutory rate (35%)	162,623	147,006	170,764
State income taxes net of federal income tax effect	41,030	38,182	42,854
Regulatory differences - utility plant items	(14,123)	(23,819)	(19,421)
Equity component of AFUDC	(6,016)	(8,012)	(15,545)
Amortization of investment tax credits	(4,729)	(4,811)	(4,871)
Flow-through / permanent differences	(2,655)	1,404	439
Amortization of Excess ADIT	(24,323)	(26,293)	28,531
Income Tax Reconciliation Provision For Uncertain Tax Positions	300	300	1,519
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0
Other - net	$ 1,229	$ 1,220	$ 1,210
Effective Income Tax Rate	15.50%	(54.60%)	15.00%
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (9,004)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ (26,801)	(26,795)	$ (26,795)
Entergy Mississippi [Member]
Utility Restructuring	395
IRS Audit Adjustment		3,768
Consolidated net income	166,834	140,583	119,925
Income Tax Expense (Benefit)	45,323	27,190	30,866
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	212,157	167,773	150,791
Income before income taxes	212,157	167,773	150,791
Computed at statutory rate (35%)	44,553	35,232	31,666
State income taxes net of federal income tax effect	9,305	6,917	5,563
Regulatory differences - utility plant items	(8,133)	(7,441)	(5,556)
Equity component of AFUDC	(1,701)	(1,412)	(1,755)
Amortization of investment tax credits	64	(540)	(160)
Flow-through / permanent differences	124	(102)	160
Amortization of Excess ADIT	0	18	(203)
Income Tax Reconciliation Provision For Uncertain Tax Positions	465	800	500
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0
Other - net	$ 251	$ 249	$ 245
Effective Income Tax Rate	21.40%	16.20%	20.50%
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (2,763)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ 0	0	$ 0
Entergy New Orleans [Member]
Utility Restructuring	(1,569)
IRS Audit Adjustment		6,819
Consolidated net income	31,798	49,338	52,629
Income Tax Expense (Benefit)	5,936	(4,207)	186
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	37,734	45,131	52,815
Income before income taxes	37,734	45,131	52,815
Computed at statutory rate (35%)	7,924	9,478	11,091
State income taxes net of federal income tax effect	2,579	2,606	3,443
Regulatory differences - utility plant items	(4,332)	(3,442)	(1,532)
Equity component of AFUDC	(498)	(1,331)	(2,088)
Amortization of investment tax credits	(56)	(61)	(88)
Flow-through / permanent differences	1,559	498	(741)
Amortization of Excess ADIT	(1,028)	(4,564)	11,724
Income Tax Reconciliation Provision For Uncertain Tax Positions	1,200	800	1,672
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0
Other - net	$ 157	$ 154	$ 153
Effective Income Tax Rate	15.70%	(9.30%)	0.40%
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (1,526)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ 0	0	$ 0
Entergy Texas [Member]
Utility Restructuring	216
IRS Audit Adjustment		2,091
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Redeemable	1,909	1,882	580
Consolidated net income	228,824	215,073	159,397
Income Tax Expense (Benefit)	25,526	3,042	(53,896)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	254,350	218,115	105,501
Income before income taxes	254,350	218,115	105,501
Computed at statutory rate (35%)	53,413	45,804	22,155
State income taxes net of federal income tax effect	1,553	1,460	360
Regulatory differences - utility plant items	(2,115)	(7,673)	(1,987)
Equity component of AFUDC	(2,077)	(9,255)	(5,973)
Amortization of investment tax credits	(617)	(617)	(617)
Flow-through / permanent differences	(475)	766	560
Amortization of Excess ADIT	(21,929)	(22,780)	69,091
Income Tax Reconciliation Provision For Uncertain Tax Positions	(2,716)	0	430
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0
Other - net	$ 273	$ 270	$ 267
Effective Income Tax Rate	10.00%	1.40%	(51.10%)
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (2,842)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ 0	0	$ 0
System Energy [Member]
Utility Restructuring	115
IRS Audit Adjustment		2,925
Consolidated net income	106,814	99,131	99,120
Income Tax Expense (Benefit)	(1,977)	20,543	15,349
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	104,837	119,674	114,469
Income before income taxes	104,837	119,674	114,469
Computed at statutory rate (35%)	22,016	25,132	24,039
State income taxes net of federal income tax effect	5,385	5,524	5,134
Regulatory differences - utility plant items	(12,776)	(2,821)	(6,213)
Equity component of AFUDC	(1,300)	(1,916)	(1,829)
Amortization of investment tax credits	(1,155)	(1,155)	(1,155)
Flow-through / permanent differences	(1,235)	(421)	(500)
Amortization of Excess ADIT	(13,354)	0	5,550
Income Tax Reconciliation Provision For Uncertain Tax Positions	200	300	1,300
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0
Other - net	$ 127	$ 125	$ 123
Effective Income Tax Rate	(1.90%)	17.20%	13.40%
Effective Income Tax Rate Reconciliation, Fitzpatrick Disposition, Amount		$ (1,300)
Effective Income Tax Rate Reconciliation, Noncontrolling Interest Income (Loss), Amount	$ 0	$ 0	$ 0

Income Taxes (Significant Compo

Income Taxes (Significant Components Of Accumulated Deferred Income Taxes And Taxes Accrued) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Plant basis differences - net	$ (6,136,563)	$ (4,795,422)
Regulatory assets for income taxes - net	(930,244)	(429,996)
Nuclear decommissioning trusts	(656,185)	(1,188,235)
Pension, net funding	(322,788)	(327,445)
Combined unitary state taxes	(7,255)	(7,723)
Deferred Tax Liability, Deferred Fuel	(85,310)	(7,667)
Other	(341,450)	(549,355)
Total	(8,687,038)	(7,314,995)
Regulatory liabilities	1,318,381	791,927
Pension and other post-employment benefits	208,128	278,486
Sale and leaseback	102,474	102,477
Compensation	79,798	89,279
Accumulated deferred investment tax credit	57,986	57,379
Provision for allowances and contingencies	82,286	71,598
Deferred Tax Assets, Power Purchase Arrangements	55,259	352,019
Net operating loss carryforwards	2,868,424	1,580,109
Capital losses and miscellaneous tax credits	11,111	21,291
Valuation allowance	(325,239)	(328,581)
Other	200,032	230,291
Deferred Tax Assets, Net of Valuation Allowance	4,963,459	4,214,739
Non-current accrued taxes (including unrecognized tax benefits)	(929,032)	(1,185,227)
Deferred Tax Liabilities, Deferred Expense	0	(9,152)
Deferred Tax Liabilities, Accumulated Storm Damage Provision	207,243	0
Deferred tax asset Nuclear Decommissioning Liabilities	278,136	968,464
Deferred Tax Liabilities, Net, Noncurrent	(4,652,611)	(4,285,483)
Deferred Tax Asset, Unbilled Revenue	26,683	0
Entergy Arkansas [Member]
Plant basis differences - net	(1,158,523)	(1,117,948)
Regulatory assets for income taxes - net	(226,687)	(188,284)
Nuclear decommissioning trusts	(175,882)	(156,123)
Pension, net funding	(92,881)	(93,486)
Deferred fuel	(27,497)	0
Other	(77,820)	(54,753)
Total	(1,759,290)	(1,610,594)
Regulatory liabilities	310,256	273,774
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions	(26,577)	(24,747)
Sale and leaseback	0	0
Compensation	3,347	2,264
Accumulated deferred investment tax credit	7,518	7,971
Provision for allowances and contingencies	24,829	22,179
Deferred Tax Assets, Power Purchase Arrangements	0	9,662
Net operating loss carryforwards	275,054	119,555
Other	19,397	16,036
Deferred Tax Assets, Net of Valuation Allowance	740,723	554,255
Accrued Income Taxes, Noncurrent	397,634	229,784
Deferred Tax Assets, Deferred Income	3,331	4,242
Deferred Tax Liabilities, Accumulated Storm Damage Provision	0
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	0	0
Deferred tax asset Nuclear Decommissioning Liabilities	123,568	123,319
Deferred Tax Liabilities, Net, Noncurrent	(1,416,201)	(1,286,123)
Entergy Louisiana [Member]
Plant basis differences - net	(3,429,473)	(2,481,976)
Regulatory assets for income taxes - net	(530,274)	(95,135)
Nuclear decommissioning trusts	(186,382)	(148,040)
Pension, net funding	(93,681)	(95,854)
Deferred fuel	(13,686)	(4,210)
Other	(138,299)	(76,735)
Total	(4,585,762)	(2,901,950)
Regulatory liabilities	634,184	218,278
Pension and other post-employment benefits	73,006	72,724
Sale and leaseback	0	0
Compensation	5,288	3,240
Accumulated deferred investment tax credit	30,666	31,155
Provision for allowances and contingencies	21,768	7,071
Deferred Tax Assets, Power Purchase Arrangements	0	3,381
Net operating loss carryforwards	1,228,547	363,806
Other	5,968	6,958
Deferred Tax Assets, Net of Valuation Allowance	2,013,578	700,307
Deferred Tax Liabilities, Prepaid Expenses	138,330	63,121
Deferred Tax Assets, Deferred Income	9,919
Deferred Tax Liabilities, Deferred Expense		(23,382)
Deferred Tax Liabilities, Accumulated Storm Damage Provision	193,967
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	5,141	9,309
Deferred tax asset Nuclear Decommissioning Liabilities	(909)	7,767
Deferred Tax Liabilities, Net, Noncurrent	(2,433,854)	(2,138,522)
Entergy Mississippi [Member]
Plant basis differences - net	(681,968)	(623,796)
Regulatory assets for income taxes - net	(34,799)	(22,381)
Nuclear decommissioning trusts	0	0
Pension, net funding	(22,253)	(24,922)
Deferred fuel	(30,409)	(1,706)
Other	(29,108)	(27,565)
Total	(798,537)	(700,370)
Regulatory liabilities	59,418	56,022
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions	(7,793)	(6,763)
Sale and leaseback	0	0
Compensation	2,181	1,670
Accumulated deferred investment tax credit	2,723	2,261
Provision for allowances and contingencies	10,236	16,799
Deferred Tax Assets, Power Purchase Arrangements	1,140	1,140
Net operating loss carryforwards	166,008	54,262
Other	2,891	3,507
Deferred Tax Assets, Net of Valuation Allowance	240,369	131,887
Accrued Income Taxes, Noncurrent	161,929	78,191
Deferred Tax Assets, Deferred Income	2,306	2,989
Deferred Tax Liabilities, Accumulated Storm Damage Provision	0
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	1,258	0
Deferred tax asset Nuclear Decommissioning Liabilities	1	0
Deferred Tax Liabilities, Net, Noncurrent	(720,097)	(646,674)
Entergy New Orleans [Member]
Plant basis differences - net	(192,660)	(83,457)
Regulatory assets for income taxes - net	(30,694)	(20,276)
Nuclear decommissioning trusts	0	0
Pension, net funding	(11,429)	(11,564)
Deferred fuel	(1,600)	(1,393)
Other	(33,071)	(26,334)
Total	(269,454)	(143,024)
Regulatory liabilities	36,057	31,248
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions	(16,090)	(13,997)
Sale and leaseback	0	0
Compensation	1,036	761
Accumulated deferred investment tax credit	4,391	4,197
Provision for allowances and contingencies	5,559	24,529
Deferred Tax Assets, Power Purchase Arrangements	0	(5,324)
Net operating loss carryforwards	105,549	26,564
Other	7,788	8,128
Deferred Tax Assets, Net of Valuation Allowance	155,805	88,881
Accrued Income Taxes, Noncurrent	251,735	284,571
Deferred Tax Assets, Deferred Income	971	877
Deferred Tax Liabilities, Accumulated Storm Damage Provision	0
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	10,977	12,317
Deferred tax asset Nuclear Decommissioning Liabilities	(433)	(419)
Deferred Tax Liabilities, Net, Noncurrent	(365,384)	(338,714)
Entergy Texas [Member]
Plant basis differences - net	(654,252)	(620,669)
Regulatory assets for income taxes - net	(45,470)	(47,684)
Nuclear decommissioning trusts	0	0
Pension, net funding	(19,914)	(19,481)
Deferred fuel	(10,139)	0
Other	(2,526)	(141)
Total	(745,577)	(687,975)
Regulatory liabilities	55,022	47,991
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions	(18,793)	(17,132)
Sale and leaseback	0	0
Compensation	1,618	1,308
Accumulated deferred investment tax credit	1,958	2,088
Deferred Tax Liabilities, Deferred Expense, Reserves and Accruals		(4,094)
Provision for allowances and contingencies	7,730
Deferred Tax Assets, Power Purchase Arrangements	(1,202)	(30,932)
Net operating loss carryforwards	81	53,052
Other	863	2,232
Deferred Tax Assets, Net of Valuation Allowance	58,450	60,543
Accrued Income Taxes, Noncurrent	5,369	11,990
Deferred Tax Assets, Deferred Income	10,196	5,909
Deferred Tax Liabilities, Accumulated Storm Damage Provision	13,276
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	883	0
Deferred tax asset Nuclear Decommissioning Liabilities	94	121
Deferred Tax Liabilities, Net, Noncurrent	(692,496)	(639,422)
System Energy [Member]
Plant basis differences - net	(433,874)	(407,125)
Regulatory assets for income taxes - net	(61,205)	(56,496)
Nuclear decommissioning trusts	(153,610)	(131,985)
Pension, net funding	(18,033)	(20,330)
Deferred fuel	(49)	(314)
Other	(5,622)	(12,521)
Total	(672,393)	(628,771)
Regulatory liabilities	224,036	163,534
Deferred tax Liability, Accrued Tax Expense, Compensation and Benefits Pensions	(1,925)	(1,344)
Sale and leaseback	102,474	102,477
Compensation	447	48
Accumulated deferred investment tax credit	10,729	9,706
Provision for allowances and contingencies	0	0
Deferred Tax Assets, Power Purchase Arrangements	0	0
Net operating loss carryforwards	0	0
Other	2	2
Deferred Tax Assets, Net of Valuation Allowance	347,153	311,353
Accrued Income Taxes, Noncurrent	57,691	42,417
Deferred Tax Assets, Deferred Income	0	0
Deferred Tax Liabilities, Accumulated Storm Damage Provision	0
Deferred Tax Assets, Capital Losses and Miscellaneous Tax Credits	1,958	7,014
Deferred tax asset Nuclear Decommissioning Liabilities	9,432	29,916
Deferred Tax Liabilities, Net, Noncurrent	$ (382,931)	$ (359,835)

Income Taxes (Schedule Of Estim

Income Taxes (Schedule Of Estimated Tax Attributes Carryovers And Their Expiration Dates) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Operating Loss Carryforwards [Line Items]
Capital losses, Carryover Amount	$ 11,111	$ 21,291
Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	6,200,000
Operating losses, Carryover Amount	21,100,000
Federal [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	0
Operating losses, Carryover Amount	4,500,000
Tax credits, Carryover Amount	4,700
Federal [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	1,700,000
Operating losses, Carryover Amount	4,500,000
Tax credits, Carryover Amount	12,300
Federal [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	0
Operating losses, Carryover Amount	2,100,000
Tax credits, Carryover Amount	1,800
Federal [Member] | Entergy New Orleans [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	900,000
Operating losses, Carryover Amount	$ 700,000
Operating losses, Year(s) of expiration	Dec. 31, 2037
Tax credits, Carryover Amount	$ 15,300
Federal [Member] | Entergy Texas [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	0
Operating losses, Carryover Amount	2,600,000
Tax credits, Carryover Amount	3,100
Federal [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Pre January 1, 2018	0
Operating losses, Carryover Amount	0
Tax credits, Carryover Amount	1,500
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	7,400,000
Operating Loss Carryforwards, No Expiration	16,700,000
Deferred Tax Assets, Charitable Contribution Carryforwards	460,800
State and Local Jurisdiction [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	4,800,000
Tax credits, Carryover Amount	0
State and Local Jurisdiction [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	7,200,000
Tax credits, Carryover Amount	0
State and Local Jurisdiction [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	2,300,000
Tax credits, Carryover Amount	1,300
State and Local Jurisdiction [Member] | Entergy New Orleans [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	1,700,000
Tax credits, Carryover Amount	0
State and Local Jurisdiction [Member] | Entergy Texas [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	0
Tax credits, Carryover Amount	$ 2,900
Tax Credit Carryforward, Expiration Date	Dec. 31, 2027
State and Local Jurisdiction [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Carryover Amount	$ 0
Tax credits, Carryover Amount	9,000
Other Federal And State [Member]
Operating Loss Carryforwards [Line Items]
Tax credits, Carryover Amount	$ 73,100
Minimum [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2023
Minimum [Member] | Federal [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2035
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2022
Minimum [Member] | State and Local Jurisdiction [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2023
Minimum [Member] | State and Local Jurisdiction [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2038
Tax Credit Carryforward, Expiration Date	Dec. 31, 2022
Minimum [Member] | State and Local Jurisdiction [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2022
Minimum [Member] | Other Federal And State [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2022
Minimum [Member] | Other Federal And State [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2038
Minimum [Member] | Other Federal And State [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2035
Minimum [Member] | Other Federal And State [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2038
Minimum [Member] | Other Federal And State [Member] | Entergy New Orleans [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2037
Minimum [Member] | Other Federal And State [Member] | Entergy Texas [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Minimum [Member] | Other Federal And State [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Minimum [Member] | Other Federal [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2022
Maximum [Member] | Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2027
Maximum [Member] | Federal [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2037
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2041
Maximum [Member] | State and Local Jurisdiction [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2026
Maximum [Member] | State and Local Jurisdiction [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Operating losses, Year(s) of expiration	Dec. 31, 2041
Tax Credit Carryforward, Expiration Date	Dec. 31, 2025
Maximum [Member] | State and Local Jurisdiction [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2025
Maximum [Member] | Other Federal And State [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | Entergy Arkansas [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | Entergy Louisiana [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | Entergy Mississippi [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | Entergy New Orleans [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | Entergy Texas [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal And State [Member] | System Energy [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2041
Maximum [Member] | Other Federal [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2026

Income Taxes (Schedule Of Unrec

Income Taxes (Schedule Of Unrecognized Tax Benefits) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	$ 5,699,339	$ 7,383,154	$ 7,181,482
Additions based on tax positions related to the current year	101,623	669,207	731,276
Additions for tax positions of prior years	33,419	98,591	151,628
Reductions for tax positions of prior years	(74,413)	(935,735)	(681,232)
Settlements	0	(1,515,878)	0
Gross balance at December 31	5,759,968	5,699,339	7,383,154
Unrecognized tax benefits net of unused tax attributes and payments	712,169	979,125	1,541,567
Remaining balances of unrecognized tax benefits, effective income tax rates	3,504,000	3,491,000	4,962,000
Net operating loss carryforwards	2,868,424	1,580,109
Offset to gross unrecognized tax benefits, credit and loss carryforward	(4,987,799)	(4,710,214)	(5,831,587)
Cash Paid To Taxing Authorities	60,000	10,000	10,000
Entergy Arkansas [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	1,364,635	1,341,242	1,298,662
Additions based on tax positions related to the current year	30,419	9,403	84,335
Additions for tax positions of prior years	15,013	13,400	20,399
Reductions for tax positions of prior years	(1,573)	(11,346)	(62,154)
Unrecognized Tax Benefits, Increase Resulting from Settlements with Taxing Authorities		11,936
Gross balance at December 31	1,408,494	1,364,635	1,341,242
Unrecognized tax benefits net of unused tax attributes and payments	415,851	252,007	207,055
Net operating loss carryforwards	275,054	119,555
Offset to gross unrecognized tax benefits, credit and loss carryforward	(992,643)	(1,112,628)	(1,134,187)
Entergy Louisiana [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	640,295	2,381,653	2,400,171
Additions based on tax positions related to the current year	13,437	35,681	28,705
Additions for tax positions of prior years	9,304	10,508	25,090
Reductions for tax positions of prior years	(58,408)	(679,601)	(72,313)
Settlements		(1,107,946)
Gross balance at December 31	604,628	640,295	2,381,653
Unrecognized tax benefits net of unused tax attributes and payments	0	0	808,396
Net operating loss carryforwards	1,228,547	363,806
Offset to gross unrecognized tax benefits, credit and loss carryforward	(604,628)	(640,295)	(1,573,257)
Entergy Mississippi [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	549,717	566,287	508,765
Additions based on tax positions related to the current year	684	5,619	68,594
Additions for tax positions of prior years	1,504	1,156	1,651
Reductions for tax positions of prior years	(2,336)	(24,173)	(12,723)
Unrecognized Tax Benefits, Increase Resulting from Settlements with Taxing Authorities		828
Gross balance at December 31	549,569	549,717	566,287
Unrecognized tax benefits net of unused tax attributes and payments	160,841	84,038	59,311
Net operating loss carryforwards	166,008	54,262
Offset to gross unrecognized tax benefits, credit and loss carryforward	(388,728)	(465,679)	(506,976)
Entergy New Orleans [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	639,546	716,773	686,687
Additions based on tax positions related to the current year	1,050	2,430	40,676
Additions for tax positions of prior years	6	294	489
Reductions for tax positions of prior years	(1,105)	(80,267)	(11,079)
Unrecognized Tax Benefits, Increase Resulting from Settlements with Taxing Authorities		316
Gross balance at December 31	639,497	639,546	716,773
Unrecognized tax benefits net of unused tax attributes and payments	154,598	187,624	271,343
Net operating loss carryforwards	105,549	26,564
Offset to gross unrecognized tax benefits, credit and loss carryforward	(484,899)	(451,922)	(445,430)
Entergy Texas [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	521,932	21,406	17,802
Additions based on tax positions related to the current year	32,616	504,362	2,312
Additions for tax positions of prior years	2,315	799	1,299
Reductions for tax positions of prior years	(4,568)	(5,559)	(7)
Unrecognized Tax Benefits, Increase Resulting from Settlements with Taxing Authorities		924
Gross balance at December 31	552,295	521,932	21,406
Unrecognized tax benefits net of unused tax attributes and payments	11,601	14,212	17,462
Net operating loss carryforwards	81	53,052
Offset to gross unrecognized tax benefits, credit and loss carryforward	(540,694)	(507,720)	(3,944)
System Energy [Member]
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Gross balance January 1	21,652	473,331	467,487
Additions based on tax positions related to the current year	1,753	4,013	5,496
Additions for tax positions of prior years	1,897	4,606	2,186
Reductions for tax positions of prior years	(1,946)	(41,466)	(1,838)
Settlements		(418,832)
Gross balance at December 31	23,356	21,652	473,331
Unrecognized tax benefits net of unused tax attributes and payments	14,780	14,239	464,939
Net operating loss carryforwards	0	0
Offset to gross unrecognized tax benefits, credit and loss carryforward	$ (8,576)	$ (7,413)	$ (8,392)

Income Taxes (Summary Of Unreco

Income Taxes (Summary Of Unrecognized Benefits That Would Affect Effective Income Tax Rate) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Unrecognized tax benefits that would impact effective income tax rate	$ 2,256	$ 2,208	$ 2,421
Entergy Arkansas [Member]
Unrecognized tax benefits that would impact effective income tax rate	262.1	259.3	203.3
Entergy Louisiana [Member]
Unrecognized tax benefits that would impact effective income tax rate	66.3	63.8	556.3
Entergy Mississippi [Member]
Unrecognized tax benefits that would impact effective income tax rate	51.7	50.7	1.9
Entergy New Orleans [Member]
Unrecognized tax benefits that would impact effective income tax rate	228.6	203.5	242.7
Entergy Texas [Member]
Unrecognized tax benefits that would impact effective income tax rate	2.6	6.1	5.7
System Energy [Member]
Unrecognized tax benefits that would impact effective income tax rate	$ 1.7	$ 0.5	$ 0

Income Taxes (Summary Of Accrue

Income Taxes (Summary Of Accrued Interest And Penalties Related To Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accrued income tax interest and penalties	$ 52	$ 44	$ 48
Entergy Arkansas [Member]
Accrued income tax interest and penalties	2.7	2.3	3.1
Entergy Louisiana [Member]
Accrued income tax interest and penalties	3.7	3.4	14.2
Entergy Mississippi [Member]
Accrued income tax interest and penalties	2.4	1.9	1.7
Entergy New Orleans [Member]
Accrued income tax interest and penalties	5.2	3.9	4.7
Entergy Texas [Member]
Accrued income tax interest and penalties	1.1	0.9	1.1
System Energy [Member]
Accrued income tax interest and penalties	$ 12.1	$ 11.9	$ 14.5

Income Taxes Income Taxes (Summ

Income Taxes Income Taxes (Summary of Interest on Income Taxes Expense Related to Unrecognized Tax Benefits) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		$ (4)
Entergy Arkansas [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	$ 0.4		$ 1.4
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		(0.8)
Entergy Louisiana [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0.3
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		(10.8)	(3.7)
Entergy Mississippi [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0.5	0.2	0.5
Entergy New Orleans [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	1.3		2
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		(0.8)
Entergy Texas [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0.2		0.2
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		(0.2)
System Energy [Member]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	$ 0.2		$ 1.3
Unrecognized Tax Expense, Income Tax Penalties and Interest Expense		$ (2.6)

Income Taxes Income Taxes (Tax

Income Taxes Income Taxes (Tax Cuts and Jobs Act) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Reduction to Regulatory Liability due to return of unprotected excess ADIT	$ 88	$ 74
Entergy Arkansas [Member]
Net Regulatory Liabilities for Income Taxes	432	467
Protected Excess ADIT	463	490
Unprotected Excess Accumulated Deferred Income Taxes	12	11
Reduction to Regulatory Liability due to return of unprotected excess ADIT	8	8
Entergy Louisiana [Member]
Net Regulatory Liabilities for Income Taxes	338	479
Protected Excess ADIT	669	721
Unprotected Excess Accumulated Deferred Income Taxes	148	223
Reduction to Regulatory Liability due to return of unprotected excess ADIT	33	31
Entergy Mississippi [Member]
Net Regulatory Liabilities for Income Taxes	212	224
Protected Excess ADIT	237	248
Entergy New Orleans [Member]
Net Regulatory Liabilities for Income Taxes	42	59
Protected Excess ADIT	56	61
Unprotected Excess Accumulated Deferred Income Taxes	0	3
Reduction to Regulatory Liability due to return of unprotected excess ADIT	1	6
Entergy Texas [Member]
Net Regulatory Liabilities for Income Taxes	171	205
Protected Excess ADIT	208	215
Unprotected Excess Accumulated Deferred Income Taxes	26	54
Reduction to Regulatory Liability due to return of unprotected excess ADIT	28	29
System Energy [Member]
Net Regulatory Liabilities for Income Taxes	113	152
Protected Excess ADIT	148	173
Unprotected Excess Accumulated Deferred Income Taxes	0	16
Reduction to Regulatory Liability due to return of unprotected excess ADIT	$ 18	$ 0

Revolving Credit Facilities, _3

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Commercial Paper Program [Member]
Commercial Paper program limit	$ 2,000
Commercial Paper	$ 1,201
Debt, weighted average interest rate	0.28%
Entergy Louisiana Waterford VIE [Member]
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Arkansas VIE [Member]
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 30
Line of credit facility, maximum borrowing capacity	150
Amount Drawn/ Outstanding	0
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5
Line of credit facility, maximum borrowing capacity	150
Amount Drawn/ Outstanding	0
Credit Facility Of Three Hundred and Fifty Million [Member] | Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	15
Line of credit facility, maximum borrowing capacity	350
Amount Drawn/ Outstanding	125
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Line of credit facility, maximum borrowing capacity	25
Amount Drawn/ Outstanding	0
Credit Facility Of Twenty Five Million [Member] | Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	10
Line of credit facility, maximum borrowing capacity	25
Amount Drawn/ Outstanding	$ 0
Credit Facility of Three Point Five Billion
Line of credit facility, commitment fee percentage	0.225%
Amount of total borrowing capacity against which fronting commitments exist	$ 20
Line of credit facility, maximum borrowing capacity	3,500
Amount Drawn/ Outstanding	$ 165
Credit Facility of Three Point Five Billion | Credit Facility [Member]
Debt, weighted average interest rate	1.60%
Credit Facility of One Hundred and Thirty Nine Million | Entergy Nuclear Vermont Yankee [Member]
Line of credit facility, commitment fee percentage	0.20%
Line of credit facility, maximum borrowing capacity	$ 139
Debt, weighted average interest rate	1.67%
Amount Drawn/ Outstanding	$ 139
Minimum [Member] | Entergy Louisiana [Member]
Line of credit facility, commitment fee percentage	0.075%
Minimum [Member] | Entergy Texas [Member]
Line of credit facility, commitment fee percentage	0.075%
Minimum [Member] | Entergy Arkansas [Member]
Line of credit facility, commitment fee percentage	0.075%
Minimum [Member] | Entergy Mississippi [Member]
Line of credit facility, commitment fee percentage	0.075%
Minimum [Member] | Entergy New Orleans [Member]
Line of credit facility, commitment fee percentage	0.075%
Maximum [Member] | Entergy Louisiana [Member]
Line of credit facility, commitment fee percentage	0.375%
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Consolidated debt ratio of lessees total capitalization	70.00%
Maximum [Member] | Entergy Texas [Member]
Line of credit facility, commitment fee percentage	0.375%
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Maximum [Member] | System Energy [Member]
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Consolidated debt ratio of lessees total capitalization	70.00%
Maximum [Member] | Entergy Arkansas [Member]
Line of credit facility, commitment fee percentage	0.375%
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Consolidated debt ratio of lessees total capitalization	70.00%
Maximum [Member] | Entergy Mississippi [Member]
Line of credit facility, commitment fee percentage	0.375%
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Maximum [Member] | Entergy New Orleans [Member]
Line of credit facility, commitment fee percentage	0.375%
Public Utilities, Approved Debt Capital Structure, Percentage	65.00%
Maximum [Member] | Credit Facility of Three Point Five Billion
Consolidated debt ratio	65.00%

Revolving Credit Facilities, _4

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) - Credit Facility of Three Point Five Billion $ in Millions	Dec. 31, 2021USD ($)
Line of credit facility, maximum borrowing capacity	$ 3,500
Amount Drawn/ Outstanding	165
Letters of Credit	6
Capacity Available	3,329
Letters of Credit Outstanding, Amount	6
Line of Credit Facility, Remaining Borrowing Capacity	$ 3,329

Revolving Credit Facilities, _5

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Credit Facilities) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Line of credit facility, maximum borrowing capacity	$ 25
Interest Rate	2.75%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Line of credit facility, maximum borrowing capacity	$ 150
Interest Rate	1.23%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Amount of total borrowing capacity against which fronting commitments exist	$ 5
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Jun. 30, 2026
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Apr. 30, 2022
Entergy Louisiana [Member] | Credit Facility Of Three Hundred and Fifty Million [Member]
Line of credit facility, maximum borrowing capacity	$ 350
Interest Rate	1.32%
Amount Drawn/ Outstanding	$ 125
Letters of Credit Outstanding, Amount	0
Amount of total borrowing capacity against which fronting commitments exist	$ 15
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Jun. 30, 2026
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Line of credit facility, maximum borrowing capacity	$ 10
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Line of credit facility, maximum borrowing capacity	$ 35
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Line of credit facility, maximum borrowing capacity	$ 37.5
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	Apr. 30, 2022
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	Apr. 30, 2022
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	Apr. 30, 2022
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Line of credit facility, maximum borrowing capacity	$ 150
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	1.3
Amount of total borrowing capacity against which fronting commitments exist	$ 30
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Jun. 30, 2026
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Line of credit facility, maximum borrowing capacity	$ 25
Interest Rate	1.73%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Amount of total borrowing capacity against which fronting commitments exist	$ 10
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Jun. 30, 2024

Revolving Credit Facilities, _6

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations (Details)	12 Months Ended
	Dec. 31, 2021USD ($)
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Uncommitted Credit Facility	$ 25,000,000
Line of Credit Facility, Commitment Fee Amount	0.0078
Letters Of Credit	8,500,000
Entergy Louisiana [Member] | Credit Facility of One Hundred and Twenty Five Million [Member]
Uncommitted Credit Facility	125,000,000
Line of Credit Facility, Commitment Fee Amount	0.0078
Letters Of Credit	15,000,000
Entergy Mississippi [Member] | Credit Facility of Sixty Five Million
Uncommitted Credit Facility	65,000,000
Line of Credit Facility, Commitment Fee Amount	0.0078
Letters Of Credit	9,300,000
Letters of credit posted to cover derivative exposure	200,000
Non-MISO Letters Of Credit	1,000,000
Entergy New Orleans [Member] | Credit Facility of Fifteen Million [Domain]
Uncommitted Credit Facility	15,000,000
Line of Credit Facility, Commitment Fee Amount	0.0100
Letters Of Credit	1,000,000
Entergy Texas [Member] | Credit Facility of Eighty Million
Uncommitted Credit Facility	80,000,000
Line of Credit Facility, Commitment Fee Amount	0.00875
Letters Of Credit	79,600,000
Letters of credit posted to cover derivative exposure	$ 100,000

Revolving Credit Facilities, _7

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Dec. 31, 2021USD ($)
Entergy Arkansas [Member]
Short-term Debt [Line Items]
Authorized	$ 250
Borrowings	140
Entergy Louisiana [Member]
Short-term Debt [Line Items]
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term Debt [Line Items]
Authorized	175
Borrowings	0
Entergy New Orleans [Member]
Short-term Debt [Line Items]
Authorized	150
Borrowings	0
Entergy Texas [Member]
Short-term Debt [Line Items]
Authorized	200
Borrowings	80
System Energy [Member]
Short-term Debt [Line Items]
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, _8

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Entergy Arkansas VIE [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date	Jun. 30, 2024
Entergy Arkansas VIE [Member] | Credit Facility of Eighty Million
Line of Credit Facility [Line Items]
Amount of Facility	$ 80
Weighted Average Interest Rate on Borrowings	1.17%
Amount Drawn/ Outstanding	$ 4.8
System Energy VIE [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date	Jun. 30, 2024
System Energy VIE [Member] | Credit Facility of One Hundred and Twenty Million
Line of Credit Facility [Line Items]
Amount of Facility	$ 120
Weighted Average Interest Rate on Borrowings	1.16%
Amount Drawn/ Outstanding	$ 36.1
Entergy Louisiana Waterford VIE [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date	Jun. 30, 2024
Entergy Louisiana Waterford VIE [Member] | Credit Facility of One Hundred and Five Million
Line of Credit Facility [Line Items]
Amount of Facility	$ 105
Weighted Average Interest Rate on Borrowings	1.16%
Amount Drawn/ Outstanding	$ 39.6
Entergy Louisiana River Bend VIE [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date	Jun. 30, 2024
Entergy Louisiana River Bend VIE [Member] | Credit Facility of One Hundred and Five Million
Line of Credit Facility [Line Items]
Amount of Facility	$ 105
Weighted Average Interest Rate on Borrowings	1.15%
Amount Drawn/ Outstanding	$ 42.7

Revolving Credit Facilities, _9

Revolving Credit Facilities, Lines Of Credit And Short-Term Borrowings (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Dec. 31, 2021USD ($)
Variable Interest Entity Notes Payable, Two Point Five One Percent Series V, Due June Twenty Twenty Seven | Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.51%
Amount	$ 70
Variable Interest Entity Notes Payable, 3.22 % Series I, Due December 2023 [Member] | Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.22%
Amount	$ 20
Variance Interest Entity notes Payable, 1.84% Series N, Due July 2026 | Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.84%
Amount	$ 90
Variable Interest Entity Notes Payable, 3.17% Series M, Due December 2023 [Member] | Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.17%
Amount	$ 40
Variable Interest Entity Notes Payable, 2.05% Series K Due September Twenty Twenty Seven | System Energy VIE [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.05%
Amount	$ 90

Long - Term Debt (Narrative) (D

Long - Term Debt (Narrative) (Details) - USD ($)	1 Months Ended							12 Months Ended
	Dec. 31, 2021	Nov. 30, 2020	Jul. 31, 2015	May 31, 2015	Jun. 30, 2010	Sep. 30, 2009	Apr. 30, 2007	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2011	Aug. 31, 2010	Nov. 30, 2009	Jun. 30, 2007
Debt Instrument [Line Items]
Year One	$ 1,040,631,000							$ 1,040,631,000
Year Two	2,460,563,000							2,460,563,000
Year Three	2,299,475,000							2,299,475,000
Year Four	1,379,140,000							1,379,140,000
Year Five	2,595,720,000							2,595,720,000
Bonds issued to recover cost	83,639,000							83,639,000	$ 174,635,000
Long-term debt								8,308,427,000	12,619,201,000	$ 9,304,396,000
System Energy [Member]
Debt Instrument [Line Items]
Year One	50,305,000							50,305,000
Year Two	250,000,000							250,000,000
Year Three	36,100,000							36,100,000
Year Four	200,000,000							200,000,000
Year Five	0							0
Long-term debt								662,423,000	1,147,903,000	1,103,917,000
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Carrying costs on issuance of bonds to recover storm damage restoration costs					$ 11,500,000
Up Front Financing Costs On Issuance Of Bonds To Recover Storm Damage Restoration Costs					$ 4,600,000
Year One	0							0
Year Two	290,000,000							290,000,000
Year Three	379,800,000							379,800,000
Year Four	0							0
Year Five	690,000,000							690,000,000
Long-term debt								719,284,000	1,071,121,000	834,038,000
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Year One	200,000,000							200,000,000
Year Two	1,445,000,000							1,445,000,000
Year Three	1,782,300,000							1,782,300,000
Year Four	300,000,000							300,000,000
Year Five	775,000,000							775,000,000
Bonds issued to recover cost	0							0	10,278,000
Long-term debt	1,200,000,000							3,769,166,000	3,675,083,000	2,691,133,000
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Up Front Financing Costs On Issuance Of Bonds To Recover Storm Damage Restoration Costs				$ 3,000,000
Year One	1,326,000							1,326,000
Year Two	171,306,000							171,306,000
Year Three	1,275,000							1,275,000
Year Four	79,140,000							79,140,000
Year Five	85,720,000							85,720,000
Amount of Hurricane Issac storm cost to be recovered through securitization				31,800,000
Replenishment amount for storm reserve spending				$ 63,900,000
Long-term debt								183,403,000	138,925,000	113,876,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Year One	0							0
Year Two	54,257,000							54,257,000
Year Three	0							0
Year Four	0							0
Year Five	130,000,000							130,000,000
Bonds issued to recover cost	53,979,000							53,979,000	123,066,000
Long-term debt								127,931,000	937,725,000	$ 986,019,000
Hurricane Rita [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Cost recovered through issuance of securitization bonds							$ 353,000,000
Amount of storm cost recovery bonds for transaction costs							6,000,000
Deferred income tax benefits							$ 32,000,000
Bonds issued to recover cost																	$ 329,500,000
Hurricane Rita [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Year Two	$ 17,500,000							$ 17,500,000
Hurricane Ike And Hurricane Gustav [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Cost recovered through issuance of securitization bonds						$ 566,400,000
Bonds issued to recover cost																$ 545,900,000
Securitization Bonds, 5.93% Series Senior Secured, Series A, Due June 2022 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.93%							5.93%
Long-term Debt, Gross	$ 0							$ 0	17,478,000
Debt Instrument, Interest Rate, Stated Percentage	5.93%							5.93%
4.0% Series First Mortgage Bonds Due March 2029 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	4.00%							4.00%
Long-term Debt, Gross	$ 300,000,000							$ 300,000,000	300,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.00%							4.00%
4.50% Series First Mortgage Bonds Due March 2039 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	4.50%							4.50%
Long-term Debt, Gross	$ 400,000,000							$ 400,000,000	400,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%							4.50%
Securitization Bonds, 2.04% Series Senior Secured, Due September 2023 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	2.04%							2.04%						2.04%
Value of non interest bearing first mortgage bonds														$ 207,200,000
Year Two	$ 11,000,000							$ 11,000,000
Long-term Debt, Gross	$ 0							$ 0	10,980,000
Debt Instrument, Interest Rate, Stated Percentage	2.04%							2.04%						2.04%
Securitization Bonds, 2.30% Series Senior Secured, Due August 2021 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage															2.30%
Value of non interest bearing first mortgage bonds															$ 124,100,000
Year One									7,300,000
Debt Instrument, Interest Rate, Stated Percentage															2.30%
Tranche A One Two Point Six Seven Percent Due June Two Thousand Twenty Seven [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.67%
Issuance Of Debt			$ 98,700,000
Debt Instrument, Interest Rate, Stated Percentage			2.67%
Securitization Bonds, 4.38% Series Senior Secured, Due November 2023 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	4.38%							4.38%
Long-term Debt, Gross	$ 54,257,000							$ 54,257,000	106,214,000
Debt Instrument, Interest Rate, Stated Percentage	4.38%							4.38%
Mortgage Bonds Zero Point Six Two Percent Series Due November 2023 | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		0.62%
Debt Instrument, Interest Rate, Stated Percentage		0.62%
Long-term debt		$ 1,100,000,000
Subsequent Event [Member] | Hurricane Ike And Hurricane Gustav [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Year Three													$ 54,300,000
Subsequent Event [Member] | Tranche A One Two Point Six Seven Percent Due June Two Thousand Twenty Seven [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Year Three													$ 12,300,000
Year Four												$ 12,500,000
Year Five											$ 6,200,000
Grand Gulf [Member] | System Energy [Member]
Debt Instrument [Line Items]
Year One	$ 17,188,000							$ 17,188,000
Year Two	17,188,000							17,188,000
Year Three	17,188,000							17,188,000
Year Four	17,188,000							17,188,000
Year Five	17,188,000							17,188,000
Regulatory Assets	0							0
Regulatory Liabilities	$ 55,600,000							$ 55,600,000	$ 55,600,000

Long - Term Debt (Schedule Of L

Long - Term Debt (Schedule Of Long-term Debt Instruments) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2011	Aug. 31, 2010
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	$ (8,273)	$ 3,665
Unamortized Debt Issuance Expense	(177,904)	(160,420)
Other	5,528	5,575
Total Long-Term Debt	25,880,901	22,369,776
Long-term Debt, Current Maturities	1,039,329	1,164,015
Long-term Debt, Excluding Current Maturities	24,841,572	21,205,761
Fair Value of Long-Term Debt	27,061,171	24,813,818
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	5,853	3,685
Unamortized Debt Issuance Expense	(20,864)	(18,108)
Total Long-Term Debt	2,179,989	1,780,577
Long-term Debt, Current Maturities	0	0
Long-term Debt, Excluding Current Maturities	2,179,989	1,780,577
Fair Value of Long-Term Debt	2,346,230	2,021,432
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	2,776	6,938
Unamortized Debt Issuance Expense	(32,803)	(30,638)
Other	1,974	1,989
Total Long-Term Debt	3,958,862	3,967,507
Long-term Debt, Current Maturities	0	485,000
Long-term Debt, Excluding Current Maturities	3,958,862	3,482,507
Fair Value of Long-Term Debt	4,176,577	4,355,632
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	(7,523)	(2,863)
Unamortized Debt Issuance Expense	(67,665)	(61,132)
Other	3,554	3,586
Total Long-Term Debt	10,914,346	9,027,451
Long-term Debt, Current Maturities	200,000	240,000
Long-term Debt, Excluding Current Maturities	10,714,346	8,787,451
Fair Value of Long-Term Debt	11,492,650	10,258,294
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	(58)	(91)
Unamortized Debt Issuance Expense	(8,665)	(8,055)
Total Long-Term Debt	788,165	642,233
Notes Payable, Related Parties, Current	1,326	1,618
Long-term Debt, Excluding Current Maturities	777,254	629,704
Long Term Debt Excluding Amount Due Within One Year	786,839	640,615
Fair Value of Long-Term Debt	765,538	620,634
Long-term debt and notes payable related parties, current		1,618
Entergy Texas [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	13,556	14,064
Unamortized Debt Issuance Expense	(18,665)	(19,048)
Total Long-Term Debt	2,354,148	2,493,708
Long-term Debt, Current Maturities	0	200,000
Long-term Debt, Excluding Current Maturities	2,354,148	2,293,708
Fair Value of Long-Term Debt	2,483,995	2,765,193
System Energy [Member]
Debt Instrument [Line Items]
Unamortized Premium and Discount - Net	(108)	(165)
Unamortized Debt Issuance Expense	(3,017)	(2,897)
Total Long-Term Debt	741,296	805,274
Long-term Debt, Current Maturities	50,329	100,015
Long-term Debt, Excluding Current Maturities	690,967	705,259
Fair Value of Long-Term Debt	$ 743,040	840,540
Mortgage Bonds Current 2018-2022 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.70%
Long-term Debt, Gross	$ 5,228,000	$ 4,978,000
Mortgage Bonds Current 2018-2022 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.62%	0.62%
Mortgage Bonds Current 2018-2022 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.59%	5.59%
Mortgage Bonds 2023-2027 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.13%
Long-term Debt, Gross	$ 3,965,000	$ 3,835,000
Mortgage Bonds 2023-2027 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.50%	1.60%
Mortgage Bonds 2023-2027 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.44%	4.44%
Mortgage Bonds 2028-2031 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.31%
Long-term Debt, Gross	$ 3,612,000	$ 2,252,000
Mortgage Bonds 2028-2031 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.75%	1.75%
Mortgage Bonds 2028-2031 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.52%	4.52%
Mortgage Bonds 2044-2066 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.06%
Long-term Debt, Gross	$ 6,980,000	$ 6,380,000
Mortgage Bonds 2044-2066 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.65%	2.65%
Mortgage Bonds 2044-2066 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%	5.50%
Mortgage Bonds 2.40% Series Due October 2026 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.40%
Long-term Debt, Gross	$ 400,000	$ 400,000
Mortgage Bonds, 2.55% Series Due June 2021 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.55%
Long-term Debt, Gross	$ 0	125,000
Mortgage Bonds 2.85% Series Due June 2028 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.85%
Long-term Debt, Gross	$ 375,000	375,000
Mortgage Bonds 4.52% Series Due December 2038 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.52%
Long-term Debt, Gross	$ 55,000	55,000
Mortgage bonds, 3.85% Series due June 2049 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.85%
Long-term Debt, Gross	$ 435,000	435,000
Mortgage Bonds Three Point Zero Five Percent Series Due June Two Thousand Thirty One [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.05%
Long-term Debt, Gross	$ 325,000	325,000
Mortgage Bonds 4.0% Series Due March 2033 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Long-term Debt, Gross	$ 750,000	750,000
Mortgage Bonds, 3.05% Series, Due June 2023 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.05%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds, 3.1% Series, Due July 2023 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.10%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds, 3.12% Series, Due September 2027 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.12%
Long-term Debt, Gross	$ 450,000	450,000
Mortgage Bonds, 3.25% Series, Due April 2028 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Long-term Debt, Gross	$ 425,000	425,000
Mortgage Bonds, 3.25% Series, Due December 2027 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.25%
Long-term Debt, Gross	$ 150,000	150,000
Mortgage Bonds, 3.3% Series, Due December 2022 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.30%
Long-term Debt, Gross	$ 200,000	200,000
Three Point Five Percent Series First Mortgage Bonds Due April Two Thousand Twenty Six [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.50%
Long-term Debt, Gross	$ 600,000	600,000
4.0% Series First Mortgage Bonds Due June 2028 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Long-term Debt, Gross	$ 350,000	350,000
Mortgage Bonds, 3.75% Series, Due February 2021 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.75%
Long-term Debt, Gross	$ 0	350,000
Mortgage Bonds, 3.75% Series, Due July 2024 [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.75%
Long-term Debt, Gross	$ 100,000	100,000
Mortgage Bonds 3.7% Series, Due June 2024 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.70%
Long-term Debt, Gross	$ 375,000	375,000
Mortgage Bonds, 3.78% Series, Due April 2025 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.78%
Long-term Debt, Gross	$ 110,000	110,000
Mortgage Bonds, 3.78 % Series Due April 2025 (Legacy) [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.78%
Long-term Debt, Gross	$ 190,000	190,000
Mortgage Bonds, 3.9% Series, Due July 2023 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.90%
Long-term Debt, Gross	$ 100,000	100,000
Mortgage Bonds, 4.0% Series, Due June 2026 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Long-term Debt, Gross	$ 85,000	85,000
Mortgage Bonds, 4.51% Series Due September 2033 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.51%
Long-term Debt, Gross	$ 60,000	60,000
Mortgage Bonds, 4.05% Series, Due September 2023 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.05%
Long-term Debt, Gross	$ 325,000	325,000
Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.90%
Long-term Debt, Gross	$ 260,000	260,000
Mortgage Bonds, 4.1% Series, Due April 2023 [Member] | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.10%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds, 4.1% Series, Due September 2021 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.10%
Long-term Debt, Gross	$ 0	75,000
Mortgage Bonds 3.45% Series Due December 2027 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.45%
Long-term Debt, Gross	$ 150,000	150,000
4.0% Series First Mortgage Bonds Due March 2029 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Long-term Debt, Gross	$ 300,000	300,000
4.50% Series First Mortgage Bonds Due March 2039 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.50%
Long-term Debt, Gross	$ 400,000	400,000
Mortgage Bonds, 4.44% Series, Due January 2026 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.44%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds, 4.8% Series, Due May 2021 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.80%
Long-term Debt, Gross	$ 0	200,000
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.875%
Long-term Debt, Gross	$ 410,000	410,000
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.875%
Long-term Debt, Gross	$ 270,000	270,000
Mortgage Bonds, 4.95% Series, Due December 2044 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.95%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds Four Point Two Percent Series Due April 2049 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Long-term Debt, Gross	$ 350,000	350,000
Mortgage Bonds, 4.95% Series, Due January 2045 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.95%
Long-term Debt, Gross	$ 450,000	450,000
Mortgage Bonds, 4.2% Series, Due September 2048 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Long-term Debt, Gross	$ 900,000	900,000
Mortgage Bonds, Four Point Two Zero Percent Series due April Twenty Fifty [Member] [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Long-term Debt, Gross	$ 525,000	525,000
Mortgage Bonds, 5.0% Series, Due July 2044 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Long-term Debt, Gross	$ 170,000	170,000
Mortgage Bonds, 5.0% Series, Due December 2052 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Long-term Debt, Gross	$ 30,000	30,000
Mortgage Bonds Five Point One Five Percent Series Due June Two Thousand Forty Five [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Long-term Debt, Gross	$ 250,000	250,000
Mortgage Bonds 3.55% Series Due September 2049 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.55%
Long-term Debt, Gross	$ 475,000	475,000
Mortgage Bonds, 5.40% Series, Due November 2024 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.40%
Long-term Debt, Gross	$ 400,000	400,000
Mortgage Bonds, 5.5% Series, Due April 2066 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Long-term Debt, Gross	$ 110,000	110,000
Mortgage Bonds, 5.59% Series, Due October 2024 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.59%
Long-term Debt, Gross	$ 300,000	300,000
Mortgage Bonds [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,195,000	1,795,000
Mortgage Bonds [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	3,660,000	3,610,000
Mortgage Bonds [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	10,490,000	8,690,000
Mortgage Bonds [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	685,000	525,000
Mortgage Bonds [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	2,305,000	2,375,000
Mortgage Bonds [Member] | System Energy [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 450,000	450,000
Governmental Bonds 2017-2022 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.43%
Long-term Debt, Gross	$ 332,680	$ 377,680
Governmental Bonds 2017-2022 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.00%	2.375%
Governmental Bonds 2017-2022 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%	3.50%
Governmental Bonds Two Point Three Seven Five Percent Series Due Two Thousand Twenty One Independence County [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.375%
Long-term Debt, Gross	$ 0	$ 45,000
Governmental Bonds, 3.50% Series, Due 2030, Louisiana Public Facilities Authority [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.50%
Long-term Debt, Gross	$ 0	115,000
Governmental Bonds 2.5% Percent Series Due 2022 Mississippi Business Finance Corporation [Member] | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Long-term Debt, Gross	$ 50,305	134,000
Governmental Bonds, 3.375% Series, Due 2028, Louisiana Public Facilities Authority [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.375%
Long-term Debt, Gross	$ 0	83,680
Governmental Bonds [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	0	45,000
Governmental Bonds [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	198,680	198,680
Governmental Bonds [Member] | System Energy [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 134,000	134,000
Securitization Bonds 2018-2027 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.31%
Long-term Debt, Gross	$ 85,234	$ 177,522
Securitization Bonds 2018-2027 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.67%	2.04%
Securitization Bonds 2018-2027 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.38%	5.93%
VIE Notes Payable 2017-2023 [Member]
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.21%
Long-term Debt, Gross	$ 310,000	$ 450,000
VIE Notes Payable 2017-2023 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.84%	2.05%
VIE Notes Payable 2017-2023 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.22%	3.92%
Variable Interest Entity Notes Payable, 3.17% Series M, Due December 2023 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.17%
Long-term Debt, Gross	$ 40,000	$ 40,000
Variable Interest Entity Notes Payable, 3.22 % Series I, Due December 2023 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.22%
Long-term Debt, Gross	$ 20,000	20,000
Variable Interest Entity Notes Payable, 3.65% Series L, Due July 2021 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.65%
Long-term Debt, Gross	$ 0	90,000
Variable Interest Entity Notes Payable, 3.42% Series J Due April 2021 [Member] | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.42%
Long-term Debt, Gross	$ 0	100,000
Variable Interest Entity Notes Payable, Three Point Ninety Two Percent Series H Due February Two Thousand Twenty One [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.92%
Long-term Debt, Gross	$ 0	40,000
Variable Interest Entity Notes Payable [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	134,800	142,200
Variable Interest Entity Notes Payable [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	172,300	188,200
Variable Interest Entity Notes Payable [Member] | System Energy [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 126,100	190,000
Securitization Bonds, 2.04% Series Senior Secured, Due September 2023 [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.04%		2.04%
Long-term Debt, Gross	$ 0	10,980
Securitization Bonds, 2.30% Series Senior Secured, Due August 2021 [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				2.30%
Securitization Bonds, 2.67% Series Senior Secured, Due June 2024 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.67%
Long-term Debt, Gross	$ 30,977	42,850
Securitization Bonds, 4.38% Series Senior Secured, Due November 2023 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.38%
Long-term Debt, Gross	$ 54,257	106,214
Securitization Bonds, 5.93% Series Senior Secured, Series A, Due June 2022 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.93%
Long-term Debt, Gross	$ 0	17,478
Securitization Bonds [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	0	10,980
Securitization Bonds [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	30,977	42,850
Securitization Bonds [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 54,257	$ 123,692
3.0% Unsecured Term Loan due May 2022 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.00%	3.00%
Long-term Debt, Gross	$ 0	$ 70,000
Entergy Corporation Notes Due July Two Thousand Twenty Two [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.00%	4.00%
Long-term Debt, Gross	$ 650,000	$ 650,000
Entergy Corporation Notes Due September Two Thousand Twenty Six [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.95%	2.95%
Long-term Debt, Gross	$ 750,000	$ 750,000
Vermont Yankee Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.67%	2.46%
Long-term Debt, Gross	$ 139,000	$ 139,000
5 Year Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.60%	2.35%
Long-term Debt, Gross	$ 165,000	$ 165,000
Entergy Arkansas VIE Credit Facility [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.17%	1.94%
Long-term Debt, Gross	$ 4,800	$ 12,200
Entergy Louisiana River Bend VIE Credit Facility [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.15%	1.95%
Long-term Debt, Gross	$ 42,700	$ 18,900
Entergy Louisiana Waterford VIE Credit Facility [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.16%	1.72%
Long-term Debt, Gross	$ 39,600	$ 39,300
System Energy VIE Credit Facility [Member] | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.16%	1.63%
Long-term Debt, Gross	$ 36,100	$ 0
Long-Term DOE Obligation [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.00%	0.00%
Long-term Debt, Gross	$ 192,115	$ 192,018
Long-Term DOE Obligation [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 192,115	$ 192,018
Grand Gulf Lease Obligation [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.00%	0.00%
Long-term Debt, Gross	$ 34,321	$ 34,336
Grand Gulf Lease Obligation, 5.13% [Member] | System Energy [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	34,321	34,336
Payable to Entergy Louisiana due November 2035 [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 10,911	$ 12,529
Entergy Corporation Notes Due September Two Thousand Twenty Five
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.90%	0.90%
Long-term Debt, Gross	$ 800,000	$ 800,000
Entergy Corporation Notes Due June Twenty Thirty
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.80%	2.80%
Long-term Debt, Gross	$ 600,000	$ 600,000
Entergy Corporation Notes Due June Twenty Fifty
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.75%	3.75%
Long-term Debt, Gross	$ 600,000	$ 600,000
Mortgage Bonds Two Point Six Five Percent Series DueJune 2051 | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.65%
Long-term Debt, Gross	$ 675,000	675,000
Mortgage Bonds Zero Point Six Two Percent Series Due November Two Thousand Twenty Three | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.62%
Long-term Debt, Gross	$ 1,100,000	1,100,000
Mortgage Bonds, One Point Six Percent Series, Due December Twenty Thirty | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.60%
Long-term Debt, Gross	$ 300,000	300,000
Mortgage Bonds, Two Point Nine Percent Series due March Twenty Fifty One | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.90%
Long-term Debt, Gross	$ 650,000	650,000
Variable Interest Entity Notes Payable, Two Point Five One Percent Series V, Due June Twenty Twenty Seven | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.51%
Long-term Debt, Gross	$ 70,000	70,000
Mortgage bonds, 3.50% Series due June 2051 | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.50%
Long-term Debt, Gross	$ 370,000	170,000
Mortgage Bonds Three Percent Series Due March Twenty Twenty Five | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.00%
Long-term Debt, Gross	$ 78,000	78,000
Mortgage Bonds, 3.75% Series Due March Twenty Forty | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.75%
Long-term Debt, Gross	$ 62,000	62,000
1.75% Series First Mortgage Bonds Due March Twenty Thirty One | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.75%
Long-term Debt, Gross	$ 600,000	600,000
Mortgage Bonds 2.14% Series Due December Twenty Twenty Five | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.14%
Long-term Debt, Gross	$ 200,000	200,000
Variable Interest Entity Notes Payable, 2.05% Series K Due September Twenty Twenty Seven | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.05%
Long-term Debt, Gross	$ 90,000	$ 90,000
Entergy Corporation Notes due June Twenty Twenty Eight
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.90%	0.00%
Long-term Debt, Gross	$ 650,000	$ 0
Entergy Corporation Notes due June Twenty Thirty One
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.40%	0.00%
Long-term Debt, Gross	$ 650,000	$ 0
Variance Interest Entity notes Payable, 1.84% Series N, Due July 2026 | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.84%
Long-term Debt, Gross	$ 90,000	0
Mortgage Bonds 0.95% Series due October 2024 | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	0.95%
Long-term Debt, Gross	$ 1,000,000	$ 0
2.5% Unsecured Term Loan due May 2023 | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%	0.00%
Long-term Debt, Gross	$ 70,000	$ 0
Mortgage Bonds 2.35% Series Due June 2032 | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.35%
Long-term Debt, Gross	$ 500,000	0
Mortgage Bonds 3.10% Series Due June 2041 | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.10%
Long-term Debt, Gross	$ 500,000	0
Governmental Bonds, 2.0%, Due 2030, Louisiana Public Facilities Authority | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.00%
Long-term Debt, Gross	$ 16,200	0
Governmental Bonds, 2.50% Series, Due 2030, Louisiana Public Facilities Authority | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.50%
Long-term Debt, Gross	$ 182,480	0
Mortgage Bonds 2.55% Series Due December 2033 | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.55%
Long-term Debt, Gross	$ 200,000	0
Mortgage Bonds, 4.19%, Due November 2031 | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.19%
Long-term Debt, Gross	$ 90,000	0
Mortgage Bonds, 4.51%, Due November 2036 | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.51%
Long-term Debt, Gross	$ 70,000	0
Mortgage Bonds 1.5% Series Due September 2026 | Entergy Texas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.50%
Long-term Debt, Gross	$ 130,000	0
Governmental Bonds 2.375% Series Due 2044 Mississippi Business Finance Corporation | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.375%
Long-term Debt, Gross	$ 83,695	$ 0
Entergy Louisiana Credit Facility
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.32%	0.00%
Long-term Debt, Gross	$ 125,000	$ 0
Entergy Louisiana Credit Facility | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.32%
Long-term Debt, Gross	$ 125,000	0
Mortgage Bonds 3.35% Series Due June 2052 | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.35%
Long-term Debt, Gross	$ 400,000	0
Credit Facility due June 2024, weighted avg rate 1.17% | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.17%
Long-term Debt, Gross	$ 4,800	12,200
Credit Facility due June 2024, weighted avg rate 1.15% | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.15%
Long-term Debt, Gross	$ 42,700	18,900
Credit Facility due June 2024, weighted avg rate 1.16% | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.16%
Long-term Debt, Gross	$ 39,600	39,300
Credit Facility due June 2024, weighted avg rate 1.16% | System Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.16%
Long-term Debt, Gross	$ 36,100	$ 0

Long - Term Debt (Schedule Of M

Long - Term Debt (Schedule Of Maturities Of Long-term Debt) (Details) $ in Thousands	Dec. 31, 2021USD ($)
Year One	$ 1,040,631
Year Two	2,460,563
Year Three	2,299,475
Year Four	1,379,140
Year Five	2,595,720
Entergy Arkansas [Member]
Year One	0
Year Two	290,000
Year Three	379,800
Year Four	0
Year Five	690,000
Entergy Louisiana [Member]
Year One	200,000
Year Two	1,445,000
Year Three	1,782,300
Year Four	300,000
Year Five	775,000
Entergy Mississippi [Member]
Year One	0
Year Two	250,000
Year Three	100,000
Year Four	0
Year Five	0
Entergy New Orleans [Member]
Year One	1,326
Year Two	171,306
Year Three	1,275
Year Four	79,140
Year Five	85,720
Entergy Texas [Member]
Year One	0
Year Two	54,257
Year Three	0
Year Four	0
Year Five	130,000
System Energy [Member]
Year One	50,305
Year Two	250,000
Year Three	36,100
Year Four	200,000
Year Five	$ 0

Long - Term Debt (Schedule Of S

Long - Term Debt (Schedule Of Senior Secured Transition Bonds) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Nov. 30, 2009	Jun. 30, 2007
Debt Instrument [Line Items]
Bonds issued to recover cost	$ 83,639	$ 174,635
Entergy Texas [Member]
Debt Instrument [Line Items]
Bonds issued to recover cost	53,979	123,066
Hurricane Rita [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Bonds issued to recover cost				$ 329,500
Hurricane Ike And Hurricane Gustav [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Bonds issued to recover cost			$ 545,900
Securitization Bonds, 5.93% Series Senior Secured, Series A, Due June 2022 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	0	17,478
Securitization Bonds, 4.38% Series Senior Secured, Due November 2023 [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 54,257	$ 106,214

Long - Term Debt Present Value

Long - Term Debt Present Value of Future Minimum Lease Payments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Year One	$ 1,040,631
Year Two	2,460,563
Year Three	2,299,475
Year Four	1,379,140
Year Five	2,595,720
Long-term Debt, Fair Value	27,061,171	$ 24,813,818
Interest Expense, Debt	863,712	837,981	$ 807,382
Total Long-Term Debt	25,880,901	22,369,776
System Energy [Member]
Year One	50,305
Year Two	250,000
Year Three	36,100
Year Four	200,000
Year Five	0
Long-term Debt, Fair Value	743,040	840,540
Interest Expense, Debt	38,393	34,467	$ 35,328
Total Long-Term Debt	741,296	$ 805,274
Grand Gulf [Member] | System Energy [Member]
Year One	17,188
Year Two	17,188
Year Three	17,188
Year Four	17,188
Year Five	17,188
Long-term Debt, Maturities, Repayments of Principal after Year Five	171,875
Long-term Debt, Fair Value	257,815
Interest Expense, Debt	223,494
Total Long-Term Debt	$ 34,321

Preferred Equity (Narratives) (

Preferred Equity (Narratives) (Details) - USD ($)	1 Months Ended						9 Months Ended	12 Months Ended
	Nov. 30, 2021	Sep. 30, 2019	Nov. 30, 2018	Nov. 30, 2017	Oct. 31, 2015	Dec. 31, 2013	Sep. 30, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 01, 2021	Apr. 30, 2021	Sep. 30, 2020
Preferred Equity [Line Items]
Preferred Stock, Value, Issued								$ 0	$ 0
Payments for Repurchase of Preferred Stock and Preference Stock								0	0	$ 50,000,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								3,438,000		$ 7,000
Stockholders' Equity Attributable to Noncontrolling Interest								$ 68,110,000	$ 35,000,000
Preferred Stock, Shares Authorized								1,000,000	0		1,000,000
Common Stock, Shares Authorized								499,000,000	500,000,000		499,000,000	500,000,000
Common Stock, Par or Stated Value Per Share								$ 0.01	$ 0.01		$ 0.01
Entergy Arkansas [Member]
Preferred Equity [Line Items]
Members' Equity Attributable to Noncontrolling Interest								$ 33,110,000	$ 0
Preferred Stock, Shares Authorized								0	0
Entergy Arkansas [Member] | AR Searcy Partnership, LLC
Preferred Equity [Line Items]
Members' Equity Attributable to Noncontrolling Interest								$ 33,110,000	$ 0
Entergy Texas [Member]
Preferred Equity [Line Items]
Stockholders' Equity Attributable to Noncontrolling Interest								$ 38,750,000	$ 35,000,000
Preferred Stock, Shares Authorized								1,550,000	1,400,000
Common Stock, Shares Authorized								200,000,000	200,000,000
Equity Method Investments								$ 300,000	$ 349,000
Preferred Stock, 8.75% Rate [Member] | Entergy Finance Holding Inc [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate						8.75%
Preferred Stock, Shares Authorized						250,000		250,000	250,000
Temporary Equity, Par Value						$ 100
Temporary Equity, Redemption Price Per Share								$ 100
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 751,000
Preferred Stock, Cumulative $1,000 Par Value 6.75% Series [Domain] | Entergy Utility Holding Company LLC [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate			6.75%
Temporary Equity, Par Value			$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 1,630,000
Preferred Units, Authorized			75,000					75,000	75,000
Preferred Stock, Cumulative One Thousand Dollar Par Value, Seven Point Five Percent Series [Member] | Entergy Utility Holding Company LLC [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate					7.50%
Temporary Equity, Par Value					$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 2,575,000
Preferred Units, Authorized					110,000			110,000	110,000
Preferred Stock, Cumulative $1,000 Par Value 6.25% Series [Domain] | Entergy Utility Holding Company LLC [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate				6.25%
Temporary Equity, Par Value				$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 634,000
Preferred Units, Authorized				15,000				15,000	15,000
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] [Domain] | Entergy Texas [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate		5.375%
Preferred Stock, Shares Authorized													1,400,000
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member]
Preferred Equity [Line Items]
Preferred stock/preferred membership interests rate	5.10%
Preferred Stock, Shares Authorized	150,000
Stockholders' Equity Attributable to Noncontrolling Interest								$ 0	$ 0
Preferred Stock, Shares Authorized								150,000	0
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Preferred Equity [Line Items]
Preferred Stock, Value, Issued		$ 35,000,000					$ 35,000,000						$ 35,000,000
Preferred stock/preferred membership interests rate							5.375%
Preferred Stock, Liquidation Preference Per Share		$ 25					$ 25						$ 25
Preferred Stock, Call Price per Share								$ 0
Stockholders' Equity Attributable to Noncontrolling Interest								$ 35,000,000	$ 35,000,000
Preferred Stock, Shares Authorized								1,400,000	1,400,000
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | On or after October 15, 2024
Preferred Equity [Line Items]
Preferred Stock, Call Price per Share									$ 25
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member]
Preferred Equity [Line Items]
Preferred Stock, Value, Issued	$ 3,750,000
Preferred Stock, Liquidation Preference Per Share	$ 25
Preferred Stock, Call Price per Share								$ 25.50
Stockholders' Equity Attributable to Noncontrolling Interest								$ 3,750,000	$ 0
Preferred Stock, Shares Authorized								150,000	0
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member] | Prior to November 1, 2026
Preferred Equity [Line Items]
Preferred Stock, Call Price per Share								$ 25.50
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member] | On or after November 1, 2026
Preferred Equity [Line Items]
Preferred Stock, Call Price per Share								$ 25

Preferred Equity (Schedule Of N

Preferred Equity (Schedule Of Number Of Shares And Units Authorized And Outstanding And Dollar Value Of Preferred Stock) (Details) - USD ($)	1 Months Ended						9 Months Ended	12 Months Ended
	Nov. 30, 2021	Sep. 30, 2019	Nov. 30, 2018	Nov. 30, 2017	Oct. 31, 2015	Dec. 31, 2013	Sep. 30, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 01, 2021	Sep. 30, 2020
Payments for Repurchase of Preferred Stock and Preference Stock								$ 0	$ 0	$ 50,000,000
Stockholders' Equity Attributable to Noncontrolling Interest								68,110,000	35,000,000
Temporary Equity, Carrying Amount, Attributable to Parent								219,410,000	219,410,000
Preferred Stock, Value, Issued								0	$ 0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 3,438,000		$ 7,000
Preferred Stock, Shares Authorized								1,000,000	0		1,000,000
Entergy Texas [Member]
Stockholders' Equity Attributable to Noncontrolling Interest								$ 38,750,000	$ 35,000,000
Preferred Stock, Shares Outstanding								1,550,000	1,400,000
Preferred Stock, Shares Authorized								1,550,000	1,400,000
Preferred Stock, Par or Stated Value Per Share								$ 25
Entergy Corporation [Member]
Preferred Stock, Shares Authorized								2,000,000	1,850,000
Temporary Equity, Shares Outstanding								1,850,000	1,850,000
Total preferred stock or preferred membership interests without sinking fund								$ 287,520,000	$ 254,410,000
Entergy Arkansas [Member]
Preferred Stock, Shares Outstanding								0	0
Preferred Stock, Shares Authorized								0	0
Entergy Arkansas [Member] | Noncontrolling Interest
Stockholders' Equity Attributable to Noncontrolling Interest								$ 33,110,000	$ 0
Utility [Member]
Preferred Shares/Units, Outstanding								1,600,000	1,600,000
Preferred Units, Authorized								1,750,000	1,600,000
Total preferred stock or preferred membership interests without sinking fund								$ 263,271,000	$ 230,161,000
Preferred Stock, 8.75% Rate [Member] | Entergy Finance Holding Inc [Member]
Preferred Stock, Shares Authorized						250,000		250,000	250,000
Temporary Equity, Shares Outstanding								250,000	250,000
Temporary Equity, Carrying Amount, Attributable to Parent								$ 24,249,000	$ 24,249,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 751,000
Preferred Stock, Dividend Rate, Percentage						8.75%
Temporary Equity, Par Value						$ 100
Temporary Equity, Redemption Price Per Share								$ 100
Preferred Stock, Cumulative One Thousand Dollar Par Value, Seven Point Five Percent Series [Member] | Entergy Utility Holding Company LLC [Member]
Preferred Shares/Units, Outstanding								110,000	110,000
Temporary Equity, Carrying Amount, Attributable to Parent								$ 107,425,000	$ 107,425,000
Preferred Units, Authorized					110,000			110,000	110,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 2,575,000
Preferred Stock, Dividend Rate, Percentage					7.50%
Temporary Equity, Par Value					$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Preferred Stock, Cumulative $1,000 Par Value 6.25% Series [Domain] | Entergy Utility Holding Company LLC [Member]
Preferred Shares/Units, Outstanding								15,000	15,000
Temporary Equity, Carrying Amount, Attributable to Parent								$ 14,366,000	$ 14,366,000
Preferred Units, Authorized				15,000				15,000	15,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 634,000
Preferred Stock, Dividend Rate, Percentage				6.25%
Temporary Equity, Par Value				$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Preferred Stock, Cumulative $1,000 Par Value 6.75% Series [Domain] | Entergy Utility Holding Company LLC [Member]
Preferred Shares/Units, Outstanding								75,000	75,000
Temporary Equity, Carrying Amount, Attributable to Parent								$ 73,370,000	$ 73,370,000
Preferred Units, Authorized			75,000					75,000	75,000
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs								$ 1,630,000
Preferred Stock, Dividend Rate, Percentage			6.75%
Temporary Equity, Par Value			$ 1,000
Temporary Equity, Redemption Price Per Share								$ 1,000
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Stockholders' Equity Attributable to Noncontrolling Interest								$ 35,000,000	$ 35,000,000
Preferred Stock, Dividend Rate, Percentage		5.375%
Preferred Stock, Shares Outstanding								1,400,000	1,400,000
Preferred Stock, Shares Authorized								1,400,000	1,400,000
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] [Domain] | Entergy Texas [Member]
Preferred Stock, Shares Authorized												1,400,000
Preferred Stock, Dividend Rate, Percentage		5.375%
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member]
Preferred Stock, Shares Authorized	150,000
Stockholders' Equity Attributable to Noncontrolling Interest								$ 0	$ 0
Preferred Stock, Dividend Rate, Percentage	5.10%
Preferred Stock, Shares Outstanding								0	0
Preferred Stock, Shares Authorized								150,000	0
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Preferred Stock, Call Price per Share								$ 0
Stockholders' Equity Attributable to Noncontrolling Interest								$ 35,000,000	$ 35,000,000
Preferred Stock, Value, Issued		$ 35,000,000					$ 35,000,000					$ 35,000,000
Preferred Stock, Dividend Rate, Percentage							5.375%
Preferred Stock, Shares Outstanding								1,400,000	1,400,000
Preferred Stock, Shares Authorized								1,400,000	1,400,000
Preferred Stock, Five Point One Zero Percent, Series B | Entergy Texas [Member]
Preferred Stock, Call Price per Share								$ 25.50
Stockholders' Equity Attributable to Noncontrolling Interest								$ 3,750,000	$ 0
Preferred Stock, Value, Issued	$ 3,750,000
Preferred Stock, Shares Outstanding								150,000	0
Preferred Stock, Shares Authorized								150,000	0

Common Equity Narrative (Detail

Common Equity Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 01, 2019	Dec. 12, 2018	Oct. 31, 2021	Aug. 31, 2021	Jun. 30, 2021	May 31, 2019	Jun. 30, 2018	Oct. 31, 2010	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Authorization of repurchase of common stock								$ 500,000
Common Stock, Dividends, Per Share, Declared									$ 3.86	$ 3.74	$ 3.66
Dividend payments received from subsidiaries									$ 136,000	$ 113,000	$ 124,000
Dividends, Common Stock, Cash									775,122	748,342	711,573
Forward Contract Indexed to Issuer's Equity, Indexed Shares						8,448,171	15,300,000
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 74.45	$ 74.45
Payments of Stock Issuance Costs		$ 728				$ 7
Proceeds from Issuance of Common Stock		$ 500,000				$ 608,000			$ 200,776	$ 0	$ 607,650
Forward Sale Agreement, Equity Offering Shares			250,743	1,692,555	416,853
Options outstanding excluded from the calculation of diluted earnings per share									1,013,320	523,999	173,290
Equity Distribution Sales Agreement, Maximum Aggregate Gross Sales Price									$ 1,000,000
Stock Issued During Period, Shares, New Issues									1,930,330
Equity Distribution Sales Agreement, Net Sales Price									$ 200,800
Equity Distribution Sales Agreement, Gross Sales Price									204,200
Equity Distribution Sales Agreement, General Issuance Costs									1,400
Equity Distribution Sales Agreement, Aggregate Compensation to Sales Agents									2,000
Forward Sale Agreement, Equity Offering Shares			250,743	1,692,555	416,853
Shares Issued, Price Per Share			$ 100.35	$ 111.16	$ 106.87
Forward Sale Agreement, Gross Sales Price			$ 25,400	$ 190,100	$ 45,000
Forward Sale Agreement, Aggregate Compensation to Sales Agents			$ 300	$ 1,900	$ 500
Authorization of Repurchase of Common Stock, Remaining									$ 350,000
Options outstanding excluded from the calculation of diluted earnings per share									1,013,320	523,999	173,290
Equity Distribution Program
Options outstanding excluded from the calculation of diluted earnings per share									1,158,917
Options outstanding excluded from the calculation of diluted earnings per share									1,158,917
Revision of Prior Period, Accounting Standards Update, Adjustment [Member]
us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleEffectOfAdoptionQuantification	$ 1,000
Increase in Retained Earnings Resulting from Implementation of ASU 2017-12	$ 8,000
Entergy Arkansas [Member]
Dividends, Common Stock, Cash									$ 50,000	$ 95,000	$ 115,000
Entergy Mississippi [Member]
Dividends, Common Stock, Cash										10,000
System Energy [Member]
Dividends, Common Stock, Cash									96,000	80,653	124,250
Common Stock [Member]
Dividends, Common Stock, Cash									$ 0	$ 0	$ 0
Forward Contract Indexed to Issuer's Equity, Shares		6,834,221							0	0	8,448,171
Stock Issued During Period, Shares, New Issues									1,930,330	0	0
Common Stock [Member] | System Energy [Member]
Dividends, Common Stock, Cash									$ 0	$ 0	$ 0

Common Equity Common Stock And

Common Equity Common Stock And Treasury Stock Shares Activity (Details) - USD ($) $ in Thousands	Dec. 12, 2018	May 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Class of Stock and Treasury Stock [Line Items]
Proceeds from Issuance of Common Stock	$ 500,000	$ 608,000	$ 200,776	$ 0	$ 607,650
Common Stock And Treasury Stock [Roll Forward]
Stock Issued During Period, Shares, New Issues			1,930,330
Common Stock [Member]
Common Stock And Treasury Stock [Roll Forward]
Beginning Balance			270,035,180	270,035,180	261,587,009
Forward Contract Indexed to Issuer's Equity, Shares	6,834,221		0	0	8,448,171
Employee Stock-Based Compensation Plans			0	0	0
Directors' Plan			0	0	0
Ending Balance			271,965,510	270,035,180	270,035,180
Stock Issued During Period, Shares, New Issues			1,930,330	0	0
Treasury Stock [Member]
Common Stock And Treasury Stock [Roll Forward]
Beginning Balance			69,790,346	70,886,400	72,530,866
Forward Contract Indexed to Issuer's Equity, Shares			0	0	0
Employee Stock-Based Compensation Plans			(461,903)	(1,076,511)	(1,624,358)
Directors' Plan			(16,117)	(19,543)	(20,108)
Ending Balance			69,312,326	69,790,346	70,886,400
Stock Issued During Period, Shares, New Issues			0	0	0

Common Equity Changes in Accumu

Common Equity Changes in Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	$ 116,679	$ (2,287)	$ 117,059
Amounts reclassified from accumulated other comprehensive income (loss)	32,919	(55,456)
Other comprehensive income (loss) before reclassifications	83,760	53,169
Accumulated other comprehensive loss, Beginning Balance	(332,528)	(449,207)
Cash flow hedges net unrealized gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	(29,754)	(55,487)
Amounts reclassified from accumulated other comprehensive income (loss)	(31,193)	(116,415)
Other comprehensive income (loss) before reclassifications	1,439	60,928
Accumulated other comprehensive loss, Beginning Balance	(1,035)	28,719
Pension and other postretirement liabilities [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	195,929	22,496
Amounts reclassified from accumulated other comprehensive income (loss)	65,558	71,609
Other comprehensive income (loss) before reclassifications	130,371	(49,113)
Accumulated other comprehensive loss, Beginning Balance	(338,647)	(534,576)
Net unrealized investment gains [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	(49,496)	30,704
Amounts reclassified from accumulated other comprehensive income (loss)	(1,446)	(10,650)
Other comprehensive income (loss) before reclassifications	(48,050)	41,354
Accumulated other comprehensive loss, Beginning Balance	7,154	56,650
Entergy Louisiana [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	3,951	(235)	10,715
Accumulated other comprehensive loss, Beginning Balance	8,278	4,327
Entergy Louisiana [Member] | Pension and other postretirement liabilities [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Net other comprehensive income (loss) for the period	3,951	(235)
Amounts reclassified from accumulated other comprehensive income (loss)	(133)	(3,237)
Other comprehensive income (loss) before reclassifications	4,084	3,002
Accumulated other comprehensive loss, Beginning Balance	$ 8,278	$ 4,327	4,562
Restatement Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated other comprehensive loss, Beginning Balance			(446,920)
Restatement Adjustment [Member] | Cash flow hedges net unrealized gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated other comprehensive loss, Beginning Balance			84,206
Restatement Adjustment [Member] | Pension and other postretirement liabilities [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated other comprehensive loss, Beginning Balance			(557,072)
Restatement Adjustment [Member] | Net unrealized investment gains [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated other comprehensive loss, Beginning Balance			$ 25,946

Common Equity Reclassifications

Common Equity Reclassifications from Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Miscellaneous - net	$ (201,778)	$ (210,633)	$ (252,539)
Investment Income, Net	430,466	392,818	547,912
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Consolidated net income	1,118,719	1,406,653	1,258,244
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(32,919)	55,456
Cash flow hedges net unrealized gain (loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications before taxes	39,485	147,360
Income Tax Expense (Benefit)	8,292	30,945
Consolidated net income	31,193	116,415
Pension and other postretirement liabilities [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications before taxes	(84,270)	(89,659)
Amortization of prior service cost/(credit)	20,947	20,769
Amortization of net loss	(88,838)	(110,185)
Settlement loss	(16,379)	(243)
Income Tax Expense (Benefit)	(18,712)	(18,050)
Consolidated net income	(65,558)	(71,609)
Net unrealized investment gains [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Investment Income, Net	2,289	16,851
Income Tax Expense (Benefit)	843	6,201
Consolidated net income	1,446	10,650
Power Contract [Member] | Cash flow hedges net unrealized gain (loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenues	39,679	147,554
Interest Rate Swap [Member] | Cash flow hedges net unrealized gain (loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Miscellaneous - net	(194)	(194)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Miscellaneous - net	(125,886)	(116,366)	(115,427)
Total reclassifications before taxes	774,393	700,028	813,160
Investment Income, Net	282,200	225,627	231,985
Income Tax Expense (Benefit)	120,409	(382,324)	121,623
Consolidated net income	653,984	1,082,352	$ 691,537
Entergy Louisiana [Member] | Pension and other postretirement liabilities [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior service credit	4,920	6,179
Total reclassifications before taxes	114	4,379
Defined Benefit Plan, Amortization of Gain (Loss)	(2,322)	(1,557)
Settlement loss	(2,484)	(243)
Income Tax Expense (Benefit)	(19)	1,142
Consolidated net income	$ 133	$ 3,237

Commitments And Contingencies_2

Commitments And Contingencies (Narrative) (Details)

Jan. 01, 2018

Oct. 31, 2021USD ($)

Aug. 31, 2021USD ($)

Jan. 31, 2021USD ($)

Oct. 31, 2020USD ($)

Apr. 30, 2020USD ($)

Jan. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Aug. 31, 2019USD ($)

Dec. 31, 2017USD ($)

Feb. 28, 2014USD ($)

Nov. 30, 2013USD ($)

Sep. 30, 2020

Dec. 31, 2023USD ($)

Dec. 31, 2022USD ($)

Dec. 31, 2021USD ($)reactorclaimprogram

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Dec. 31, 2016USD ($)

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)

Dec. 31, 2026USD ($)

Oct. 01, 2012USD ($)

Commitments And Contingencies [Line Items]

Proceeds from insurance

$ 0

$ 0

$ 7,040,000

Number of financial protection programs | program

2

Insurance coverage for public liability by American Nuclear Insurers

$ 450,000,000

Maximum retrospective insurance premium obligation per reactor per incident

137,600,000

Maximum retrospective insurance premium obligation per incident

826,000,000

Rate of maximum retrospective premium per year per nuclear power reactor

21,000,000

ANI combined with Secondary Financial Protection Coverage

13,500,000,000

Additional damage coverage for a terrorist event

$ 100,000,000,000

Number of nuclear reactor included in the Secondary Financial Protection program | reactor

95

Total premium for reactor under secondary financial protection program

$ 13,000,000,000

Maximum recovery nuclear insurance policies for property damage caused by Terrorist Act

3,240,000,000

Maximum conventional property insurance coverage on an each and every loss basis

400,000,000

Minimum value of power plants, substations to be covered under conventional property insurance

5,000,000

Purchase of terrorism insurance coverage

$ 400,000,000

Reduction in fee Entergy’s nuclear owner/licensee subsidiaries have been charged related to spent nuclear fuel storage

$ 0

Percentage of Weekly Indemnity Paid After Deductible Second Period has Passed

80.00%

Percentage of Weekly Indemnity Paid After Deductible Final Period has Passed

80.00%

Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent

21.00%

35.00%

35.00%

Increase (Decrease) in Regulatory Liabilities

$ 43,631,000

238,669,000

(14,781,000)

Percentage of Weekly Indemnity Paid After Deductible First Period has Passed

100.00%

Grand Gulf [Member]

Commitments And Contingencies [Line Items]

Ownership percentage by a non-affiliated company

10.00%

Operational Perils [Member]

Commitments And Contingencies [Line Items]

Self-insured retention per occurrence

$ 20,000,000

Earthquake and Flood [Member]

Commitments And Contingencies [Line Items]

Maximum conventional property insurance coverage on an each and every loss basis

400,000,000

Self-insured retention per occurrence

40,000,000

Named Windstorm and Associated Storm Surge [Member]

Commitments And Contingencies [Line Items]

Maximum conventional property insurance coverage on an each and every loss basis

125,000,000

Self-insured retention per occurrence

40,000,000

Non-Nuclear and Non-Radioactive Damage [Member] | Pilgrim, Palisades, and Indian Point [Member]

Commitments And Contingencies [Line Items]

Primary Insurance Layer Conditions Of Coverage

500,000,000

Wind, Flood, Earthquake and Volcanic Eruption [Member] | Palisades [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

$ 10,000,000

Percentage of Additional Property Insurance Deductible for Loss in Excess of Deductible

10.00%

Maximum Additional Property Insurance Deductible

$ 50,000,000

Wind, Flood, Earthquake and Volcanic Eruption [Member] | Big Rock Point [Member]

Commitments And Contingencies [Line Items]

Maximum Additional Property Insurance Deductible

14,000,000

Flood event [Member] | ANO and Grand Gulf [Member]

Commitments And Contingencies [Line Items]

Primary Insurance Layer Conditions Of Coverage

500,000,000

Utility [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

$ 10,000,000

Utility [Member] | Asbestos Issue [Member]

Commitments And Contingencies [Line Items]

Number of asbestos lawsuits | claim

200

Number of claimants in asbestos lawsuits | claim

325

Utility [Member] | Primary Layer [Member]

Commitments And Contingencies [Line Items]

Property Insurance insured amount per occurrence

$ 1,500,000,000

Utility [Member] | Blanket Layer [Member]

Commitments And Contingencies [Line Items]

Property Insurance insured amount per occurrence

100,000,000

Utility [Member] | Earthquake and Volcanic Eruption [Member]

Commitments And Contingencies [Line Items]

Primary Insurance Layer Conditions Of Coverage

500,000,000

Utility [Member] | Flood event [Member] | River Bend and Waterford 3 [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

$ 10,000,000

Percentage of Additional Property Insurance Deductible for Loss in Excess of Deductible

10.00%

Maximum Additional Property Insurance Deductible

$ 50,000,000

Entergy Wholesale Commodities [Member] | Palisades [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

10,000,000

Entergy Wholesale Commodities [Member] | Big Rock Point [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

5,000,000

Entergy Wholesale Commodities [Member] | Primary Layer [Member] | Palisades [Member]

Commitments And Contingencies [Line Items]

Property Insurance insured amount per occurrence

1,115,000,000

Entergy Wholesale Commodities [Member] | Primary Layer [Member] | Big Rock Point [Member]

Commitments And Contingencies [Line Items]

Property Insurance insured amount per occurrence

50,000,000

Nuclear [Member] | Wind [Member]

Commitments And Contingencies [Line Items]

Property Insurance Deductible

$ 10,000,000

Percentage of Additional Property Insurance Deductible for Loss in Excess of Deductible

10.00%

Maximum Additional Property Insurance Deductible

$ 50,000,000

Entergy Mississippi [Member]

Commitments And Contingencies [Line Items]

Percentage of capacity and energy agreed to sell by system energy from grand gulf

33.00%

Average monthly payments under unit power sales agreement

$ 14,600,000

Purchased Percentage Of Capacity And Energy Based On Agreement

31.30%

Amortization period of cost

27 years

Allocated amortization cost in percentage

43.97%

Increase (Decrease) in Regulatory Liabilities

$ 21,930,000

(18,672,000)

(21,524,000)

Entergy Texas [Member]

Commitments And Contingencies [Line Items]

Increase (Decrease) in Regulatory Liabilities

$ (28,747,000)

(57,477,000)

(105,517,000)

System Energy [Member]

Commitments And Contingencies [Line Items]

Number of nuclear power reactors | reactor

1

Increase (Decrease) in Regulatory Liabilities

$ 40,884,000

140,965,000

130,949,000

Ownership

90.00%

System Energy [Member] | Grand Gulf [Member]

Commitments And Contingencies [Line Items]

Damages awarded for previously capitalized costs

$ 5,000,000

Damages awarded for previously recorded operation and maintenance

10,000,000

Damages awarded for previously recorded nuclear fuel expense

21,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 40,500,000

Entergy New Orleans [Member]

Commitments And Contingencies [Line Items]

Percentage of capacity and energy agreed to sell by system energy from grand gulf

17.00%

Average monthly payments under unit power sales agreement

$ 7,900,000

Purchased Percentage Of Capacity And Energy Based On Agreement

24.70%

Amortization period of cost

27 years

Allocated amortization cost in percentage

29.80%

Increase (Decrease) in Regulatory Liabilities

$ 4,985,000

(4,728,000)

(22,105,000)

Entergy New Orleans [Member] | Flood, Earthquake and Named Windstorm [Member]

Commitments And Contingencies [Line Items]

Maximum conventional property insurance coverage on an each and every loss basis

50,000,000

Entergy Louisiana [Member]

Commitments And Contingencies [Line Items]

Payments made under purchased power agreement

$ 128,500,000

132,700,000

135,500,000

Required energy for the production of Vidalia project in percentage

94.00%

Credit rates agreed by subsidiary for each year under settlement related to tax benefits from tax treatment of purchased power agreement

$ 11,000,000

Number of years for which credit rates agreed by subsidiary under settlement related to tax benefits from the tax treatment of purchased power agreement

10 years

Proceeds from insurance

$ 0

$ 0

7,040,000

Number of nuclear power reactors | reactor

2

Percentage of capacity and energy agreed to sell by system energy from grand gulf

14.00%

Average monthly payments under unit power sales agreement

$ 6,500,000

Purchased Percentage Of Capacity And Energy Based On Agreement

26.90%

Amortization period of cost

27 years

Allocated amortization cost in percentage

26.23%

Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent

21.00%

Increase (Decrease) in Regulatory Liabilities

$ (16,478,000)

$ 71,698,000

(35,881,000)

Entergy Louisiana [Member] | State of Louisiana Enacted Tax Legislation 2021

Commitments And Contingencies [Line Items]

State Effective Income Tax Rate, Percent

8.00%

Entergy Louisiana [Member] | Waterford 3 [Member]

Commitments And Contingencies [Line Items]

Damages awarded for previously capitalized costs

$ 5,000,000

Damages awarded for previously recorded operation and maintenance

8,000,000

Damages awarded for previously recorded nuclear fuel expense

20,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 33,000,000

Entergy Louisiana [Member] | River Bend [Member]

Commitments And Contingencies [Line Items]

Damages awarded for previously capitalized costs

$ 9,000,000

$ 2,000,000

Damages awarded for previously recorded operation and maintenance

4,000,000

5,000,000

Damages awarded for previously recorded nuclear fuel expense

8,000,000

12,000,000

Litigation Settlement, Amount Awarded from Other Party

21,000,000

$ 19,000,000

Entergy Louisiana [Member] | Subsequent Event [Member]

Commitments And Contingencies [Line Items]

Estimated Payments Under Purchased Power Agreement in Next Twelve Months

$ 137,000,000

Estimated Payments Under Purchased Power Agreement in Year Two and Thereafter

$ 1,230,000,000

Amount of remaining benefits of tax credit by crediting rate payers

$ 20,235,000

Maximum period up to which remaining benefit of tax accounting election shared

15 years

Entergy Louisiana [Member] | Subsequent Event [Member] | State of Louisiana Enacted Tax Legislation 2021

Commitments And Contingencies [Line Items]

State Effective Income Tax Rate, Percent

7.50%

Entergy Arkansas [Member]

Commitments And Contingencies [Line Items]

Estimated cost to restore ANO to service

$ 95,000,000

Proceeds From Insurance Settlement, Operating and Investing Activities

$ 50,000,000

Number of nuclear power reactors | reactor

2

Percentage of capacity and energy agreed to sell by system energy from grand gulf

36.00%

Average monthly payments under unit power sales agreement

$ 16,400,000

Purchased Percentage Of Capacity And Energy Based On Agreement

17.10%

Amortization period of cost

27 years

Incremental NRC Inspection Costs

$ 53,000,000

NRC inspection and performance improvement costs

$ 7,000,000

$ 44,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 21,000,000

Increase (Decrease) in Regulatory Liabilities

$ 21,066,000

$ 106,878,000

$ 39,293,000

State Effective Income Tax Rate, Percent

6.50%

6.20%

Entergy Arkansas [Member] | ANO [Member]

Commitments And Contingencies [Line Items]

Deferred Fuel and Purchased Energy Costs Excluded From Revised Energy Cost Rate

$ 65,900,000

Damages awarded for previously capitalized costs

$ 55,000,000

Damages awarded for previously recorded operation and maintenance

12,000,000

Damages awarded for previously recorded nuclear fuel expense

12,000,000

Damages awarded for previously recorded taxes other than income taxes

1,000,000

Reduction of previously recorded deprecation expense

$ 5,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 80,000,000

Entergy Arkansas [Member] | Subsequent Event [Member]

Commitments And Contingencies [Line Items]

State Effective Income Tax Rate, Percent

5.70%

5.90%

Entergy Wholesale Commodities [Member] | FitzPatrick [Member]

Commitments And Contingencies [Line Items]

Litigation Settlement, Amount Awarded from Other Party

7,000,000

Asset Write-Offs, Impairments, And Related Charges

$ 7,000,000

Entergy Wholesale Commodities [Member] | Palisades [Member]

Commitments And Contingencies [Line Items]

Damages awarded for previously capitalized costs

$ 16,000,000

Damages awarded for previously recorded operation and maintenance

7,000,000

Reduction of previously recorded deprecation expense

9,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 23,000,000

Entergy Wholesale Commodities [Member] | Big Rock Point [Member]

Commitments And Contingencies [Line Items]

Insurance coverage for public liability by American Nuclear Insurers

$ 44,400,000

Entergy Wholesale Commodities [Member] | Indian Point [Member]

Commitments And Contingencies [Line Items]

Damages awarded for previously capitalized costs

$ 32,000,000

Damages awarded for previously recorded operation and maintenance

47,000,000

Damages awarded for previously recorded taxes other than income taxes

4,000,000

Litigation Settlement, Amount Awarded from Other Party

$ 83,000,000

Entergy Wholesale Commodities [Member] | Pilgrim [Member]

Commitments And Contingencies [Line Items]

Litigation Settlement, Amount Awarded from Other Party

$ 37,600,000

Vidalia Purchased Power Agreement [Member]

Commitments And Contingencies [Line Items]

Increase (Decrease) in Regulatory Liabilities

$ (30,500,000)

Commitments And Contingencies_3

Commitments And Contingencies (Maximum Amounts Of Possible Assessments Per Occurrence) (Details) - Insurance-related Assessments [Member] $ in Thousands	Dec. 31, 2021USD ($)
Entergy Arkansas [Member]
Commitments And Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	$ 27,600
Entergy Louisiana [Member]
Commitments And Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	49,200
Entergy Mississippi [Member]
Commitments And Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	110
Entergy New Orleans [Member]
Commitments And Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	110
System Energy [Member]
Commitments And Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss	$ 21,400

Asset Retirement Obligations (N

Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Decommissioning Fund Investments	$ 5,514,016	$ 7,253,215
Asset Retirement Obligation	4,757,100	6,469,500	$ 6,159,200
Entergy Louisiana [Member]
Decommissioning Fund Investments	2,114,523	1,794,042
Asset Retirement Obligation	1,653,200	1,573,300	1,497,300
System Energy [Member]
Decommissioning Fund Investments	1,385,254	1,215,868
Asset Retirement Obligation	1,007,600	968,900	931,700
Entergy Arkansas [Member]
Decommissioning Fund Investments	1,438,416	1,273,921
Asset Retirement Obligation	1,390,400	1,314,200	1,242,600
Entergy Mississippi [Member]
Asset Retirement Obligation	$ 10,300	$ 9,800	$ 9,700

Asset Retirement Obligations (D

Asset Retirement Obligations (Difference Between Estimated Incurred Removal Costs And Estimated Removal Costs Recovered In Rates) (Details) - Removal Costs [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Entergy Arkansas [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	$ 224.3	$ 212.6
Entergy Louisiana [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	848.2	302.5
Entergy Mississippi [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	136.8	107.3
Entergy New Orleans [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	91.7	63.2
Entergy Texas [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	98.1	115.3
System Energy [Member]
Asset Retirement Obligations [Line Items]
Regulatory Assets	$ 89.7	$ 92.9

Asset Retirement Obligations (C

Asset Retirement Obligations (Cumulative Decommissioning And Retirement Cost Liabilities And Expenses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	$ 4,757.1	$ 6,469.5	$ 6,159.2
Accretion	317.9	394.6
Spending	(1,997.1)
Asset Retirement Obligation, Period Increase (Decrease)	33.2	84.3
Entergy Arkansas [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	1,390.4	1,314.2	1,242.6
Accretion	77.7	73.3
Spending	(1.5)
Asset Retirement Obligation, Period Increase (Decrease)	0	1.7
Entergy Louisiana [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	1,653.2	1,573.3	1,497.3
Accretion	79.9	76
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0
Entergy Mississippi [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	10.3	9.8	9.7
Accretion	0.5	0.6
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0.5
Entergy New Orleans [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	4	3.8	3.5
Accretion	0.2	0.3
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0
Entergy Texas [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	8.5	8.1	7.6
Accretion	0.4	0.5
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0
System Energy [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	1,007.6	968.9	931.7
Accretion	38.7	37.2
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0
Entergy Wholesale Commodities [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	0.6	0.5	0.5
Accretion	0.1	0
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	0	0
Big Rock Point [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	42	41.1	40.3
Accretion	3.4	3.3
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	2.5	2.5
Indian Point 1 [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	0	246.6	238.6
Accretion	8.8	20.4
Spending	(254.1)
Asset Retirement Obligation, Period Increase (Decrease)	1.3	12.4
Indian Point 2 [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	0	839.8	829
Accretion	28.9	69.4
Spending	(843.6)
Asset Retirement Obligation, Period Increase (Decrease)	25.1	58.6
Indian Point 3 [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	0	869.4	808.4
Accretion	29.1	67.4
Spending	(897.9)
Asset Retirement Obligation, Period Increase (Decrease)	0.6	6.4
Palisades [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation	640.4	594.1	$ 549.8
Accretion	50.1	46.4
Spending	0
Asset Retirement Obligation, Period Increase (Decrease)	$ 3.8	$ 2.1

Leases (Narrative) (Details)

Leases (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 1988
Operating Lease, Expense	$ 69,067,000	$ 67,471,000
Finance Lease, Right-of-Use Asset, Amortization	12,483,000	12,180,000
Finance Lease, Interest Expense	2,845,000	2,884,000
Short-term Lease, Cost	$ 2,800,000	$ 759,000
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Public Utilities, Property, Plant and Equipment, Plant in Service	Public Utilities, Property, Plant and Equipment, Plant in Service
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Public Utilities, Property, Plant and Equipment, Plant in Service	Public Utilities, Property, Plant and Equipment, Plant in Service
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset	$ 56,099,000	$ 55,840,000
Finance Lease, Right-of-Use Asset	15,043,000	12,447,000
Operating Lease, Expense	15,087,000	14,344,000
Finance Lease, Right-of-Use Asset, Amortization	2,860,000	2,693,000
Finance Lease, Interest Expense	432,000	408,000
Short-term Lease, Cost	826,000	43,000
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset	46,443,000	43,189,000
Finance Lease, Right-of-Use Asset	19,007,000	16,425,000
Operating Lease, Expense	14,368,000	13,944,000
Finance Lease, Right-of-Use Asset, Amortization	3,938,000	4,097,000
Finance Lease, Interest Expense	607,000	597,000
Short-term Lease, Cost	934,000	719,000
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset	16,831,000	16,538,000
Finance Lease, Right-of-Use Asset	9,114,000	7,452,000
Operating Lease, Expense	7,018,000	6,584,000
Finance Lease, Right-of-Use Asset, Amortization	1,766,000	1,627,000
Finance Lease, Interest Expense	270,000	254,000
Short-term Lease, Cost	703,000
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset	5,480,000	5,222,000
Finance Lease, Right-of-Use Asset	4,023,000	3,428,000
Operating Lease, Expense	1,745,000	1,443,000
Finance Lease, Right-of-Use Asset, Amortization	731,000	712,000
Finance Lease, Interest Expense	124,000	120,000
Short-term Lease, Cost	77,000
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset	14,986,000	14,738,000
Finance Lease, Right-of-Use Asset	7,583,000	5,719,000
Operating Lease, Expense	5,370,000	4,870,000
Finance Lease, Right-of-Use Asset, Amortization	1,493,000	1,340,000
Finance Lease, Interest Expense	214,000	196,000
Short-term Lease, Cost	261,000
System Energy [Member] | Grand Gulf [Member]
Sale Leaseback Transaction, Net Book Value			$ 500,000,000
Regulatory Assets	0
Net regulatory liability related to sale and leaseback transaction	$ 55,600,000	$ 55,600,000

Leases Purchase Power Agreement

Leases Purchase Power Agreement Minimum Lease Payments (Details) $ in Thousands	Dec. 31, 2021USD ($)
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 65,270
Lessee, Operating Lease, Liability, Payments, Due Year Two	55,527
Lessee, Operating Lease, Liability, Payments, Due Year Three	48,281
Lessee, Operating Lease, Liability, Payments, Due Year Four	28,174
Lessee, Operating Lease, Liability, Payments, Due	227,647
Entergy Louisiana [Member]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	13,706
Lessee, Operating Lease, Liability, Payments, Due Year Two	11,791
Lessee, Operating Lease, Liability, Payments, Due Year Three	9,618
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,694
Lessee, Operating Lease, Liability, Payments, Due	49,464
Entergy Texas [Member]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	4,888
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,449
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,427
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,933
Lessee, Operating Lease, Liability, Payments, Due	$ 15,891

Leases (Future Minimum Lease Pa

Leases (Future Minimum Lease Payments Sale Leaseback Transactions) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Year One	$ 1,040,631
Year Two	2,460,563
Year Three	2,299,475
Year Four	1,379,140
Year Five	2,595,720
Long-term Debt, Fair Value	27,061,171	$ 24,813,818
Interest Expense, Debt	863,712	837,981	$ 807,382
Total Long-Term Debt	25,880,901	22,369,776
System Energy [Member]
Year One	50,305
Year Two	250,000
Year Three	36,100
Year Four	200,000
Year Five	0
Long-term Debt, Fair Value	743,040	840,540
Interest Expense, Debt	38,393	34,467	35,328
Total Long-Term Debt	741,296	805,274
System Energy [Member] | Grand Gulf [Member]
Year One	17,188
Year Two	17,188
Year Three	17,188
Year Four	17,188
Year Five	17,188
Long-term Debt, Maturities, Repayments of Principal after Year Five	171,875
Long-term Debt, Fair Value	257,815
Interest Expense, Debt	223,494
Total Long-Term Debt	34,321
Entergy Louisiana [Member]
Year One	200,000
Year Two	1,445,000
Year Three	1,782,300
Year Four	300,000
Year Five	775,000
Long-term Debt, Fair Value	11,492,650	10,258,294
Interest Expense, Debt	350,227	331,352	$ 309,493
Total Long-Term Debt	$ 10,914,346	$ 9,027,451

Leases Lease, Cost (Details)

Leases Lease, Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Operating Lease, Expense	$ 69,067	$ 67,471
Finance Lease, Right-of-Use Asset, Amortization	12,483	12,180
Finance Lease, Interest Expense	2,845	2,884
Short-term Lease, Cost	2,800	759
Entergy Louisiana [Member]
Operating Lease, Expense	14,368	13,944
Finance Lease, Right-of-Use Asset, Amortization	3,938	4,097
Finance Lease, Interest Expense	607	597
Short-term Lease, Cost	934	719
Entergy Mississippi [Member]
Operating Lease, Expense	7,018	6,584
Finance Lease, Right-of-Use Asset, Amortization	1,766	1,627
Finance Lease, Interest Expense	270	254
Short-term Lease, Cost	703
Entergy New Orleans [Member]
Operating Lease, Expense	1,745	1,443
Finance Lease, Right-of-Use Asset, Amortization	731	712
Finance Lease, Interest Expense	124	120
Short-term Lease, Cost	77
Entergy Texas [Member]
Operating Lease, Expense	5,370	4,870
Finance Lease, Right-of-Use Asset, Amortization	1,493	1,340
Finance Lease, Interest Expense	214	196
Short-term Lease, Cost	261
Entergy Arkansas [Member]
Operating Lease, Expense	15,087	14,344
Finance Lease, Right-of-Use Asset, Amortization	2,860	2,693
Finance Lease, Interest Expense	432	408
Short-term Lease, Cost	$ 826	$ 43

Leases Lease, Assets (Details)

Leases Lease, Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset	$ 46,443	$ 43,189
Finance Lease, Right-of-Use Asset	19,007	16,425
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset	16,831	16,538
Finance Lease, Right-of-Use Asset	9,114	7,452
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset	5,480	5,222
Finance Lease, Right-of-Use Asset	4,023	3,428
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset	14,986	14,738
Finance Lease, Right-of-Use Asset	7,583	5,719
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset	56,099	55,840
Finance Lease, Right-of-Use Asset	$ 15,043	$ 12,447

Leases Lease, Liabilities (Deta

Leases Lease, Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 8 days	4 years 9 months 25 days
Finance Lease, Weighted Average Remaining Lease Term	6 years 2 months 4 days	6 years 4 months 2 days
Operating Lease, Weighted Average Discount Rate, Percent	3.37%	3.58%
Finance Lease, Weighted Average Discount Rate, Percent	3.96%	4.42%
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Current	Other Liabilities, Current
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Current	Other Liabilities, Current
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Deferred Credits and Other Liabilities	Deferred Credits and Other Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Deferred Credits and Other Liabilities	Deferred Credits and Other Liabilities
Entergy Louisiana [Member]
Operating Lease, Liability, Current	$ 12,520	$ 11,934
Finance Lease, Liability, Current	4,001	3,821
Operating Lease, Liability, Noncurrent	33,931	31,260
Finance Lease, Liability, Noncurrent	$ 15,006	$ 12,603
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days	4 years 8 months 19 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 6 months 25 days	5 years 2 months 12 days
Operating Lease, Weighted Average Discount Rate, Percent	2.93%	3.11%
Finance Lease, Weighted Average Discount Rate, Percent	3.08%	3.33%
Entergy Mississippi [Member]
Operating Lease, Liability, Current	$ 5,866	$ 5,738
Finance Lease, Liability, Current	1,843	1,644
Operating Lease, Liability, Noncurrent	10,976	10,867
Finance Lease, Liability, Noncurrent	$ 7,271	$ 5,808
Operating Lease, Weighted Average Remaining Lease Term	5 years 4 months 9 days	5 years 3 months 18 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 7 months 17 days	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.00%	3.43%
Finance Lease, Weighted Average Discount Rate, Percent	2.87%	3.22%
Entergy New Orleans [Member]
Operating Lease, Liability, Current	$ 1,491	$ 1,406
Finance Lease, Liability, Current	812	686
Operating Lease, Liability, Noncurrent	3,994	3,819
Finance Lease, Liability, Noncurrent	$ 3,211	$ 2,741
Operating Lease, Weighted Average Remaining Lease Term	5 years 4 months 6 days	5 years 9 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 11 months 8 days	5 years 8 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	2.99%	3.09%
Finance Lease, Weighted Average Discount Rate, Percent	3.03%	3.35%
Entergy Texas [Member]
Operating Lease, Liability, Current	$ 4,489	$ 4,277
Finance Lease, Liability, Current	1,476	1,327
Operating Lease, Liability, Noncurrent	10,505	10,469
Finance Lease, Liability, Noncurrent	$ 6,107	$ 4,392
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 8 days	4 years 3 months 18 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 11 months 19 days	5 years 4 months 20 days
Operating Lease, Weighted Average Discount Rate, Percent	3.04%	3.07%
Finance Lease, Weighted Average Discount Rate, Percent	2.79%	3.22%
Entergy Arkansas [Member]
Operating Lease, Liability, Current	$ 12,695	$ 11,942
Finance Lease, Liability, Current	2,964	2,660
Operating Lease, Liability, Noncurrent	43,420	43,914
Finance Lease, Liability, Noncurrent	$ 12,079	$ 9,788
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 17 days	5 years 8 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 10 months 20 days	5 years 7 months 6 days
Operating Lease, Weighted Average Discount Rate, Percent	3.10%	3.34%
Finance Lease, Weighted Average Discount Rate, Percent	2.80%	3.18%

Leases Lease, Terms and Discoun

Leases Lease, Terms and Discount Rate (Details)	Dec. 31, 2021	Dec. 31, 2020
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 8 days	4 years 9 months 25 days
Finance Lease, Weighted Average Remaining Lease Term	6 years 2 months 4 days	6 years 4 months 2 days
Operating Lease, Weighted Average Discount Rate, Percent	3.37%	3.58%
Finance Lease, Weighted Average Discount Rate, Percent	3.96%	4.42%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days	4 years 8 months 19 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 6 months 25 days	5 years 2 months 12 days
Operating Lease, Weighted Average Discount Rate, Percent	2.93%	3.11%
Finance Lease, Weighted Average Discount Rate, Percent	3.08%	3.33%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	5 years 4 months 9 days	5 years 3 months 18 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 7 months 17 days	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.00%	3.43%
Finance Lease, Weighted Average Discount Rate, Percent	2.87%	3.22%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	5 years 4 months 6 days	5 years 9 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 11 months 8 days	5 years 8 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	2.99%	3.09%
Finance Lease, Weighted Average Discount Rate, Percent	3.03%	3.35%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 8 days	4 years 3 months 18 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 11 months 19 days	5 years 4 months 20 days
Operating Lease, Weighted Average Discount Rate, Percent	3.04%	3.07%
Finance Lease, Weighted Average Discount Rate, Percent	2.79%	3.22%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 17 days	5 years 8 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 10 months 20 days	5 years 7 months 6 days
Operating Lease, Weighted Average Discount Rate, Percent	3.10%	3.34%
Finance Lease, Weighted Average Discount Rate, Percent	2.80%	3.18%

Leases Lease, Maturity (Details

Leases Lease, Maturity (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2021USD ($)
Lessee, Operating Lease, Liability, Payments, Due Year Two	$ 55,527
Finance Lease, Liability, Payments, Due Year Two	14,611
Lessee, Operating Lease, Liability, Payments, Due Year Three	48,281
Finance Lease, Liability, Payments, Due Year Three	13,296
Lessee, Operating Lease, Liability, Payments, Due Year Four	28,174
Finance Lease, Liability, Payments, Due Year Four	11,913
Lessee, Operating Lease, Liability, Payments, Due Year Five	15,864
Finance Lease, Liability, Payments, Due Year Five	10,061
Lessee, Operating Lease, Liability, Payments, Due after Year Five	14,531
Finance Lease, Liability, Payments, Due after Year Five	15,756
Lessee, Operating Lease, Liability, Payments, Due	227,647
Finance Lease, Liability, Payments, Due	80,949
Operating Lease, Cost	15,847
Finance Lease, Interest Payment on Liability	8,640
Present Value Net Minimum Operating Lease Payments	211,800
Present Value Net Minimum Financing Lease Payments	72,309
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	65,270
Finance Lease, Liability, Payments, Due Next Twelve Months	15,312
Entergy Louisiana [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	11,791
Finance Lease, Liability, Payments, Due Year Two	4,231
Lessee, Operating Lease, Liability, Payments, Due Year Three	9,618
Finance Lease, Liability, Payments, Due Year Three	3,671
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,694
Finance Lease, Liability, Payments, Due Year Four	3,122
Lessee, Operating Lease, Liability, Payments, Due Year Five	4,081
Finance Lease, Liability, Payments, Due Year Five	2,367
Lessee, Operating Lease, Liability, Payments, Due after Year Five	3,574
Finance Lease, Liability, Payments, Due after Year Five	2,613
Lessee, Operating Lease, Liability, Payments, Due	49,464
Finance Lease, Liability, Payments, Due	20,485
Operating Lease, Cost	3,013
Finance Lease, Interest Payment on Liability	1,478
Present Value Net Minimum Operating Lease Payments	46,451
Present Value Net Minimum Financing Lease Payments	19,007
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	13,706
Finance Lease, Liability, Payments, Due Next Twelve Months	4,481
Entergy Mississippi [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,181
Finance Lease, Liability, Payments, Due Year Two	1,971
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,174
Finance Lease, Liability, Payments, Due Year Three	1,783
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,168
Finance Lease, Liability, Payments, Due Year Four	1,529
Lessee, Operating Lease, Liability, Payments, Due Year Five	827
Finance Lease, Liability, Payments, Due Year Five	1,202
Lessee, Operating Lease, Liability, Payments, Due after Year Five	1,924
Finance Lease, Liability, Payments, Due after Year Five	1,220
Lessee, Operating Lease, Liability, Payments, Due	18,554
Finance Lease, Liability, Payments, Due	9,759
Operating Lease, Cost	1,711
Finance Lease, Interest Payment on Liability	645
Present Value Net Minimum Operating Lease Payments	16,843
Present Value Net Minimum Financing Lease Payments	9,114
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	6,280
Finance Lease, Liability, Payments, Due Next Twelve Months	2,054
Entergy New Orleans [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	1,441
Finance Lease, Liability, Payments, Due Year Two	814
Lessee, Operating Lease, Liability, Payments, Due Year Three	1,182
Finance Lease, Liability, Payments, Due Year Three	712
Lessee, Operating Lease, Liability, Payments, Due Year Four	773
Finance Lease, Liability, Payments, Due Year Four	621
Lessee, Operating Lease, Liability, Payments, Due Year Five	398
Finance Lease, Liability, Payments, Due Year Five	545
Lessee, Operating Lease, Liability, Payments, Due after Year Five	601
Finance Lease, Liability, Payments, Due after Year Five	673
Lessee, Operating Lease, Liability, Payments, Due	6,077
Finance Lease, Liability, Payments, Due	4,219
Operating Lease, Cost	592
Finance Lease, Interest Payment on Liability	196
Present Value Net Minimum Operating Lease Payments	5,485
Present Value Net Minimum Financing Lease Payments	4,023
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	1,682
Finance Lease, Liability, Payments, Due Next Twelve Months	854
Entergy Texas [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,449
Finance Lease, Liability, Payments, Due Year Two	1,532
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,427
Finance Lease, Liability, Payments, Due Year Three	1,382
Lessee, Operating Lease, Liability, Payments, Due Year Four	1,933
Finance Lease, Liability, Payments, Due Year Four	1,256
Lessee, Operating Lease, Liability, Payments, Due Year Five	771
Finance Lease, Liability, Payments, Due Year Five	1,016
Lessee, Operating Lease, Liability, Payments, Due after Year Five	423
Finance Lease, Liability, Payments, Due after Year Five	1,296
Lessee, Operating Lease, Liability, Payments, Due	15,891
Finance Lease, Liability, Payments, Due	8,119
Operating Lease, Cost	898
Finance Lease, Interest Payment on Liability	536
Present Value Net Minimum Operating Lease Payments	14,993
Present Value Net Minimum Financing Lease Payments	7,583
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	4,888
Finance Lease, Liability, Payments, Due Next Twelve Months	1,637
Entergy Arkansas [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	12,713
Finance Lease, Liability, Payments, Due Year Two	3,100
Lessee, Operating Lease, Liability, Payments, Due Year Three	11,150
Finance Lease, Liability, Payments, Due Year Three	2,791
Lessee, Operating Lease, Liability, Payments, Due Year Four	9,292
Finance Lease, Liability, Payments, Due Year Four	2,449
Lessee, Operating Lease, Liability, Payments, Due Year Five	7,314
Finance Lease, Liability, Payments, Due Year Five	2,018
Lessee, Operating Lease, Liability, Payments, Due after Year Five	5,892
Finance Lease, Liability, Payments, Due after Year Five	2,477
Lessee, Operating Lease, Liability, Payments, Due	60,541
Finance Lease, Liability, Payments, Due	16,154
Operating Lease, Cost	4,425
Finance Lease, Interest Payment on Liability	1,111
Present Value Net Minimum Operating Lease Payments	56,116
Present Value Net Minimum Financing Lease Payments	15,043
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	14,180
Finance Lease, Liability, Payments, Due Next Twelve Months	$ 3,319

Retirement, Other Postretirem_3

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Narrative (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Jan. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
non-current pension liability		$ 1,949,325	$ 2,853,013
Current pension liability		$ 68,336	$ 61,815
Ultimate healthcare cost trend rate		4.75%	4.75%
Defined Benefit Plan, Plan Assets, Payment for Settlement		$ (553,576)	$ (84,754)
Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		165,500	161,300
Net periodic benefit costs		28,600	18,100	$ 22,600
Settlement charges related to the payment of lump sum benefits out of the plan		10,900		7,400
Projected benefit obligation		181,600	182,400
Accumulated other comprehensive income (before taxes)		17,000	16,700
Amortization of prior service credit		74,900	77,300
Defined Benefit Plan Benefit Obligation, Current		26,300	22,900
Defined Benefit Plan Benefit Obligation, Non-Current		155,300	159,500
Common Stock Issued, Employee Stock Trust		35,000
Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		6,993,110	6,854,426	6,271,160
Projected benefit obligation		8,409,620	9,143,652	8,406,203
non-current pension liability		1,416,510	2,289,226
Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		6,993,110	6,854,426
Accumulated pension benefit obligation		7,800,000	8,400,000
Net periodic benefit costs		471,815	373,784	276,969
Expected Employer Contributions		200,000
Defined Contribution Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Subsidiaries' contribution to defined contribution plan		$ 62,300	63,100	57,600
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	500.00%	6.00%
Defined Contribution Plan Discretionary Employer Matching Contribution Percent	400.00%
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		$ 771,319	737,866	686,262
Net periodic benefit costs		(25,580)	(17,184)	(5,593)
Projected benefit obligation		1,189,682	1,181,075	1,252,903
non-current pension liability		376,363	404,246
Current pension liability		42,000	38,963
Accumulated other comprehensive income (before taxes)		(34,350)	(59,216)
Amortization of prior service credit		(33,069)	(32,882)	(35,377)
Expected Employer Contributions		42,800
Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
non-current pension liability		185,789	361,682
Defined Benefit Plan, Plan Assets, Payment for Settlement		(104,400)	(48,400)
Entergy Arkansas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		2,482	2,626
Net periodic benefit costs		343	333	275
Projected benefit obligation		2,875	3,197
non-current pension liability		2,627	2,979
Current pension liability		248	218
Accumulated other comprehensive income (before taxes)		0	0
Entergy Arkansas [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		1,302,588	1,285,856	1,200,035
Projected benefit obligation		1,579,346	1,739,382	1,615,084
non-current pension liability		276,758	453,526
Entergy Arkansas [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		1,463,966	1,617,858
Net periodic benefit costs		92,919	81,723	44,400
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		315,495	304,192	284,224
Net periodic benefit costs		(11,084)	(10,075)	(10,747)
Projected benefit obligation		221,183	209,369	185,744
Current pension liability		0	0
Accumulated other comprehensive income (before taxes)		0	0
Amortization of prior service credit		(1,121)	(1,849)	(4,950)
Expected Employer Contributions		517
Entergy Arkansas [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		40,840
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
non-current pension liability		528,213	692,728
Defined Benefit Plan, Plan Assets, Payment for Settlement		(166,600)	(18,600)
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		1,445	1,802
Net periodic benefit costs		307	148	159
Projected benefit obligation		1,469	1,965
non-current pension liability		1,283	1,772
Current pension liability		186	193
Accumulated other comprehensive income (before taxes)		10	18
Settlement charges		155
Entergy Louisiana [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		1,446,658	1,476,306	1,364,030
Projected benefit obligation		1,736,396	1,927,271	1,784,474
non-current pension liability		289,738	450,965
Entergy Louisiana [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		1,574,273	1,753,980
Net periodic benefit costs		117,150	70,648	48,630
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		0	0	0
Net periodic benefit costs		5,410	5,583	7,259
Projected benefit obligation		253,031	255,571	274,175
non-current pension liability		237,192	239,991
Current pension liability		15,839	15,580
Accumulated other comprehensive income (before taxes)		(34,518)	(37,792)
Amortization of prior service credit		(4,920)	(6,179)	(7,349)
Expected Employer Contributions		15,845
Entergy Louisiana [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		22,917
Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
non-current pension liability		59,065	110,901
Defined Benefit Plan, Plan Assets, Payment for Settlement		(45,700)	(7,700)
Entergy Mississippi [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		3,377	3,345
Net periodic benefit costs		365	359	326
Projected benefit obligation		3,708	3,852
non-current pension liability		3,518	3,671
Current pension liability		190	181
Accumulated other comprehensive income (before taxes)		0	0
Settlement charges				40
Entergy Mississippi [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		356,424	371,394	354,928
Projected benefit obligation		448,858	510,109	471,510
non-current pension liability		92,434	138,715
Entergy Mississippi [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		407,851	466,497
Net periodic benefit costs		33,826	20,184	11,331
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		97,888	93,475	86,085
Net periodic benefit costs		(4,677)	(3,644)	(2,100)
Projected benefit obligation		61,001	61,990	65,979
Current pension liability		0	0
Accumulated other comprehensive income (before taxes)		0	0
Amortization of prior service credit		(1,775)	(1,652)	(1,756)
Expected Employer Contributions		130
Entergy Mississippi [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		12,852
Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Payment for Settlement		(14,300)
Entergy New Orleans [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		738	240
Net periodic benefit costs		30	31	20
Projected benefit obligation		1,069	247
non-current pension liability		1,039	230
Current pension liability		31	17
Accumulated other comprehensive income (before taxes)		0	0
Entergy New Orleans [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		172,366	172,551	160,777
Projected benefit obligation		195,380	220,287	206,962
non-current pension liability		23,014	47,736
Entergy New Orleans [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		178,010	201,159
Net periodic benefit costs		9,859	5,988	5,101
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		111,137	102,734	93,858
Net periodic benefit costs		(6,420)	(4,929)	(3,450)
Projected benefit obligation		31,866	31,707	38,460
Current pension liability		0	0
Accumulated other comprehensive income (before taxes)		0	0
Amortization of prior service credit		(916)	(763)	(682)
Expected Employer Contributions		175
Entergy New Orleans [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		922
Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Payment for Settlement		(31,900)	(9,800)
Difference between rate case pension amounts and actuarially determined pension amounts		14,600
Entergy Texas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		7,355	7,949
Net periodic benefit costs		615	469	481
Projected benefit obligation		7,462	8,475
non-current pension liability		4,382	7,842
Current pension liability		3,080	633
Accumulated other comprehensive income (before taxes)		0	0
Settlement charges		172
Entergy Texas [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		341,915	349,748	339,126
Projected benefit obligation		371,802	410,664	396,764
non-current pension liability		29,887	60,916
Entergy Texas [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		342,441	379,050
Net periodic benefit costs		18,617	12,358	5,740
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		182,285	174,096	161,810
Net periodic benefit costs		(10,883)	(8,873)	(6,503)
Projected benefit obligation		71,961	74,233	94,742
Current pension liability		0	0
Accumulated other comprehensive income (before taxes)		0	0
Amortization of prior service credit		(3,742)	(3,364)	(2,243)
Expected Employer Contributions		66
Entergy Texas [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		1,924
System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
non-current pension liability		76,104	125,412
Defined Benefit Plan, Plan Assets, Payment for Settlement		(33,000)	(236)
System Energy [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		312,060	310,818	282,668
Projected benefit obligation		394,794	441,148	393,607
non-current pension liability		82,734	130,330
System Energy [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation		366,920	410,296
Net periodic benefit costs		29,348	17,341	12,345
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Amount		54,650	52,619	48,471
Net periodic benefit costs		(1,313)	(1,518)	(1,009)
Projected benefit obligation		47,875	47,701	47,348
Current pension liability		0	0
Accumulated other comprehensive income (before taxes)		0	0
Amortization of prior service credit		(436)	$ (1,065)	$ (1,450)
Expected Employer Contributions		22
System Energy [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected Employer Contributions		$ 12,760
Minimum [Member] | Defined Contribution Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match		70.00%
Maximum [Member] | Defined Contribution Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent of Match	100.00%	100.00%
Domestic Equity Securities [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		39.00%
Domestic Equity Securities [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		25.00%
Domestic Equity Securities [Member] | Minimum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		32.00%
Domestic Equity Securities [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		20.00%
Domestic Equity Securities [Member] | Maximum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		46.00%
Domestic Equity Securities [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		30.00%
International Equity Securities [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		19.00%
International Equity Securities [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		17.00%
International Equity Securities [Member] | Minimum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		15.00%
International Equity Securities [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		12.00%
International Equity Securities [Member] | Maximum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		23.00%
International Equity Securities [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		22.00%
Fixed Income Securities [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		42.00%
Fixed Income Securities [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		58.00%
Fixed Income Securities [Member] | Minimum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		39.00%
Fixed Income Securities [Member] | Minimum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		53.00%
Fixed Income Securities [Member] | Maximum [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		45.00%
Fixed Income Securities [Member] | Maximum [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation		63.00%
Defined Benefit Plan Total Plan Assets | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage		10.00%
Defined Benefit Plan Total Plan Assets | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage		10.00%

Retirement, Other Postretirem_4

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Net Periodic Pension Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 26,578	$ 24,500	$ 18,699
Interest cost	21,278	28,597	47,901
Expected return on assets	(43,220)	(40,880)	(38,246)
Amortization of prior service credit	(33,069)	(32,882)	(35,377)
Recognized net loss	2,853	3,481	1,430
Net periodic pension costs	(25,580)	(17,184)	(5,593)
Prior service credit for period	(3,168)	(128,837)	0
Net (gain)/loss	6,210	41,031	(38,526)
Amortization of prior service cost/(credit)	33,069	32,882	35,377
Amortization of net loss	2,853	3,481	1,430
Total	33,258	(58,405)	(4,579)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	7,678	(75,589)	(10,172)
Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	165,500	161,300
Amortization of prior service credit	74,900	77,300
Net periodic pension costs	28,600	18,100	22,600
Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	7,800,000	8,400,000
Service cost - benefits earned during the period	165,278	161,487	134,193
Interest cost	191,107	239,614	293,114
Expected return on assets	(424,572)	(414,273)	(414,947)
Recognized net loss	334,124	350,010	241,117
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(205,878)	(36,946)	(23,492)
Net periodic pension costs	471,815	373,784	276,969
Net (gain)/loss	(448,532)	483,653	614,600
Amortization of net loss	(334,124)	(358,473)	(241,117)
Total	(988,534)	88,234	349,991
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(516,719)	462,018	626,960
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	4,135	3,626	2,363
Interest cost	3,726	4,712	7,226
Expected return on assets	(18,020)	(17,104)	(15,962)
Amortization of prior service credit	(1,121)	(1,849)	(4,950)
Recognized net loss	196	540	576
Net periodic pension costs	(11,084)	(10,075)	(10,747)
Prior service credit for period	85	(12,320)
Net (gain)/loss	9,956	2,245	(26,707)
Amortization of prior service cost/(credit)	1,121	1,849	4,950
Amortization of net loss	196	540	576
Total	10,796	15,874	(22,333)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(288)	5,799	(33,080)
Entergy Arkansas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	2,482	2,626
Net periodic pension costs	343	333	275
Entergy Arkansas [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	1,463,966	1,617,858
Service cost - benefits earned during the period	28,632	26,329	21,043
Interest cost	35,683	44,165	56,701
Expected return on assets	(78,368)	(78,187)	(80,705)
Recognized net loss	69,290	68,338	47,361
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(37,682)	(21,078)
Net periodic pension costs	92,919	81,723	44,400
Net (gain)/loss	(96,066)	106,178	118,898
Amortization of net loss	(69,290)	(69,713)	47,361
Total	(203,038)	15,387	71,537
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(110,119)	97,110	115,937
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,174	5,993	4,639
Interest cost	4,520	6,216	10,664
Expected return on assets	0	0	0
Amortization of prior service credit	(4,920)	(6,179)	(7,349)
Recognized net loss	(364)	(447)	(695)
Net periodic pension costs	5,410	5,583	7,259
Prior service credit for period	(357)	23,508
Net (gain)/loss	(2,367)	8,744	(2,220)
Amortization of prior service cost/(credit)	4,920	6,179	7,349
Amortization of net loss	(364)	(447)	(695)
Total	3,274	(8,138)	5,824
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	8,684	(2,555)	13,083
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	1,445	1,802
Net periodic pension costs	307	148	159
Entergy Louisiana [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	1,574,273	1,753,980
Service cost - benefits earned during the period	38,271	35,158	29,137
Interest cost	39,740	50,432	63,529
Expected return on assets	(89,821)	(89,691)	(90,607)
Recognized net loss	67,015	66,640	46,571
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(61,945)	(8,109)
Net periodic pension costs	117,150	70,648	48,630
Net (gain)/loss	(89,534)	90,064	99,346
Amortization of net loss	(67,015)	(68,248)	46,571
Total	(218,494)	13,707	52,775
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(101,344)	84,355	101,405
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,448	1,468	1,046
Interest cost	1,110	1,536	2,681
Expected return on assets	(5,536)	(5,167)	(4,794)
Amortization of prior service credit	(1,775)	(1,652)	(1,756)
Recognized net loss	76	171	723
Net periodic pension costs	(4,677)	(3,644)	(2,100)
Prior service credit for period	0	4,428
Net (gain)/loss	(2,823)	(4,456)	(11,950)
Amortization of prior service cost/(credit)	1,775	1,652	1,756
Amortization of net loss	76	171	723
Total	(1,124)	(7,403)	(10,917)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(5,801)	(11,047)	(13,017)
Entergy Mississippi [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	3,377	3,345
Net periodic pension costs	365	359	326
Entergy Mississippi [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	407,851	466,497
Service cost - benefits earned during the period	9,070	8,060	6,516
Interest cost	10,446	12,922	16,272
Expected return on assets	(22,407)	(23,147)	(23,873)
Recognized net loss	20,007	18,983	12,416
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(16,710)	(3,366)
Net periodic pension costs	33,826	20,184	11,331
Net (gain)/loss	(29,675)	36,899	41,088
Amortization of net loss	(20,007)	(19,393)	12,416
Total	(66,392)	14,140	28,672
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(32,566)	34,324	40,003
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	437	445	367
Interest cost	521	784	1,581
Expected return on assets	(5,750)	(5,382)	(4,947)
Amortization of prior service credit	(916)	(763)	(682)
Recognized net loss	(712)	(13)	231
Net periodic pension costs	(6,420)	(4,929)	(3,450)
Prior service credit for period	0	5,493
Net (gain)/loss	(3,330)	(5,351)	(10,967)
Amortization of prior service cost/(credit)	916	763	682
Amortization of net loss	(712)	(13)	231
Total	(1,702)	(10,068)	(10,516)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(8,122)	(14,997)	(13,966)
Entergy New Orleans [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	738	240
Net periodic pension costs	30	31	20
Entergy New Orleans [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	178,010	201,159
Service cost - benefits earned during the period	3,038	2,654	2,274
Interest cost	4,392	5,825	7,495
Expected return on assets	(10,598)	(10,509)	(10,785)
Recognized net loss	7,596	8,018	6,117
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(5,431)	0
Net periodic pension costs	9,859	5,988	5,101
Net (gain)/loss	(16,159)	8,148	6,531
Amortization of net loss	(7,596)	(8,213)	6,117
Total	(29,186)	(65)	414
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(19,327)	5,923	5,515
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,384	1,219	943
Interest cost	1,269	2,008	3,415
Expected return on assets	(10,192)	(9,643)	(9,103)
Amortization of prior service credit	(3,742)	(3,364)	(2,243)
Recognized net loss	398	907	485
Net periodic pension costs	(10,883)	(8,873)	(6,503)
Prior service credit for period	3,776	22,441
Net (gain)/loss	939	(3,266)	(6,406)
Amortization of prior service cost/(credit)	3,742	3,364	2,243
Amortization of net loss	398	907	485
Total	507	(23,250)	(4,648)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(10,376)	(32,123)	(11,151)
Entergy Texas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	7,355	7,949
Net periodic pension costs	615	469	481
Entergy Texas [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	342,441	379,050
Service cost - benefits earned during the period	6,921	6,116	5,401
Interest cost	8,381	10,731	14,451
Expected return on assets	(21,158)	(21,951)	(23,447)
Recognized net loss	12,676	13,173	9,335
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(11,797)	(4,289)
Net periodic pension costs	18,617	12,358	5,740
Net (gain)/loss	(18,217)	13,379	10,869
Amortization of net loss	(12,676)	(13,564)	9,335
Total	(42,690)	(4,474)	1,534
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(24,073)	7,884	7,274
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,340	1,254	973
Interest cost	878	1,130	1,902
Expected return on assets	(3,156)	(2,958)	(2,788)
Amortization of prior service credit	(436)	(1,065)	(1,450)
Recognized net loss	61	121	354
Net periodic pension costs	(1,313)	(1,518)	(1,009)
Prior service credit for period	(69)	1,963
Net (gain)/loss	210	58	(5,539)
Amortization of prior service cost/(credit)	436	1,065	1,450
Amortization of net loss	61	121	354
Total	654	(961)	(4,443)
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	(659)	(2,479)	(5,452)
System Energy [Member] | Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated pension benefit obligation	366,920	410,296
Service cost - benefits earned during the period	8,851	7,883	6,199
Interest cost	9,087	11,006	13,456
Expected return on assets	(19,254)	(18,757)	(18,710)
Recognized net loss	18,404	17,104	11,400
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement	(12,260)	(105)
Net periodic pension costs	29,348	17,341	12,345
Net (gain)/loss	(27,617)	35,403	36,711
Amortization of net loss	(18,404)	(17,434)	11,400
Total	(58,281)	17,864	25,311
Total recognized as net periodic benefit cost, regulatory asset, and/or AOCI (before tax)	$ (28,933)	$ 35,205	$ 37,656

Retirement, Other Postretirem_5

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Benefit Obligations, Plan Assets, Funded Status, Amounts Recognized In The Balance Sheet (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Amounts recognized in the balance sheet
Current liabilities	$ (68,336)	$ (61,815)
Non-current liabilities	(1,949,325)	(2,853,013)
Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	1,181,075	1,252,903
Service cost	26,578	24,500	$ 18,699
Interest cost	21,278	28,597	47,901
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,168)	(128,837)
Actuarial (gain)/loss	20,955	80,162
Employee contributions	22,023	37,176
Benefits Paid	(79,308)	(113,786)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	249	360
Balance at end of year	1,189,682	1,181,075	1,252,903
Change in Plan Assets
Fair value of assets at beginning of year	737,866	686,262
Actual return on plan assets	57,965	80,011
Employer contributions	32,773	48,203
Employee contributions	22,023	37,176
Benefits Paid	(79,308)	(113,786)
Fair value of assets at end of year	771,319	737,866	686,262
Funded status	(418,363)	(443,209)
Amounts recognized in the balance sheet
Current liabilities	(42,000)	(38,963)
Non-current liabilities	(376,363)	(404,246)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	(37,693)	(45,501)
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	7,981	8,565
Defined Benefit Plan Regulatory Liability Before Tax	(45,674)	(54,066)
Amounts recognized as AOCI (before tax)
Prior service cost	(61,488)	(83,581)
Net loss	27,138	24,365
Accumulated other comprehensive income (before taxes)	(34,350)	(59,216)
Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	9,143,652	8,406,203
Service cost	165,278	161,487
Interest cost	191,107	239,614
Actuarial (gain)/loss	(158,276)	969,609
Benefits Paid	(932,141)	(633,261)
Balance at end of year	8,409,620	9,143,652	8,406,203
Change in Plan Assets
Fair value of assets at beginning of year	6,854,426	6,271,160
Actual return on plan assets	714,827	900,229
Employer contributions	355,998	316,298
Benefits Paid	(932,141)	(633,261)
Fair value of assets at end of year	6,993,110	6,854,426	6,271,160
Funded status	(1,416,510)	(2,289,226)
Amounts recognized in the balance sheet
Non-current liabilities	(1,416,510)	(2,289,226)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(2,214,390)	(2,926,670)
Amounts recognized as AOCI (before tax)
Net loss	449,756	726,010
Entergy Arkansas [Member]
Amounts recognized in the balance sheet
Non-current liabilities	(185,789)	(361,682)
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	209,369	185,744
Service cost	4,135	3,626	2,363
Interest cost	3,726	4,712	7,226
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(85)	12,320
Actuarial (gain)/loss	14,323	18,257
Employee contributions	5,637	7,792
Benefits Paid	(15,954)	(23,141)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	32	59
Balance at end of year	221,183	209,369	185,744
Change in Plan Assets
Fair value of assets at beginning of year	304,192	284,224
Actual return on plan assets	22,387	33,116
Employer contributions		2,201
Defined Benefit Plan Refund to Employer	(767)
Employee contributions	5,637	7,792
Benefits Paid	(15,954)	(23,141)
Fair value of assets at end of year	315,495	304,192	284,224
Funded status	94,312	94,823
Amounts recognized in the balance sheet
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	94,312	94,823
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	8,691	7,655
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	6,797	16,557
Defined Benefit Plan Regulatory Liability Before Tax	(1,894)	(8,902)
Amounts recognized as AOCI (before tax)
Prior service cost	0	0
Net loss	0	0
Accumulated other comprehensive income (before taxes)	0	0
Entergy Arkansas [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	1,739,382	1,615,084
Service cost	28,632	26,329
Interest cost	35,683	44,165
Actuarial (gain)/loss	(41,227)	196,755
Benefits Paid	(183,124)	(142,951)
Balance at end of year	1,579,346	1,739,382	1,615,084
Change in Plan Assets
Fair value of assets at beginning of year	1,285,856	1,200,035
Actual return on plan assets	133,207	168,764
Employer contributions	66,649	60,008
Benefits Paid	(183,124)	(142,951)
Fair value of assets at end of year	1,302,588	1,285,856	1,200,035
Funded status	(276,758)	(453,526)
Amounts recognized in the balance sheet
Non-current liabilities	(276,758)	(453,526)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(612,963)	(816,002)
Amounts recognized as AOCI (before tax)
Net loss	0	0
Entergy Louisiana [Member]
Amounts recognized in the balance sheet
Non-current liabilities	(528,213)	(692,728)
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	255,571	274,175
Service cost	6,174	5,993	4,639
Interest cost	4,520	6,216	10,664
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	357	(23,508)
Actuarial (gain)/loss	(2,367)	8,744
Employee contributions	5,186	8,269
Benefits Paid	(16,460)	(24,395)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	50	77
Balance at end of year	253,031	255,571	274,175
Change in Plan Assets
Fair value of assets at beginning of year	0	0
Actual return on plan assets	0	0
Employer contributions	11,274	16,126
Employee contributions	5,186	8,269
Benefits Paid	(16,460)	(24,395)
Fair value of assets at end of year	0	0	0
Funded status	(253,031)	(255,571)
Amounts recognized in the balance sheet
Current liabilities	(15,839)	(15,580)
Non-current liabilities	(237,192)	(239,991)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	0	0
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	0	0
Amounts recognized as AOCI (before tax)
Prior service cost	(16,967)	(22,244)
Net loss	(17,551)	(15,548)
Accumulated other comprehensive income (before taxes)	(34,518)	(37,792)
Entergy Louisiana [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	1,927,271	1,784,474
Service cost	38,271	35,158
Interest cost	39,740	50,432
Actuarial (gain)/loss	(28,439)	196,032
Benefits Paid	(240,447)	(138,825)
Balance at end of year	1,736,396	1,927,271	1,784,474
Change in Plan Assets
Fair value of assets at beginning of year	1,476,306	1,364,030
Actual return on plan assets	150,917	195,658
Employer contributions	59,882	55,443
Benefits Paid	(240,447)	(138,825)
Fair value of assets at end of year	1,446,658	1,476,306	1,364,030
Funded status	(289,738)	(450,965)
Amounts recognized in the balance sheet
Non-current liabilities	(289,738)	(450,965)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(556,345)	(766,099)
Amounts recognized as AOCI (before tax)
Net loss	23,181	31,921
Entergy Mississippi [Member]
Amounts recognized in the balance sheet
Non-current liabilities	(59,065)	(110,901)
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	61,990	65,979
Service cost	1,448	1,468	1,046
Interest cost	1,110	1,536	2,681
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(4,428)
Actuarial (gain)/loss	(1,335)	684
Employee contributions	1,386	2,122
Benefits Paid	(3,604)	(5,382)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	6	11
Balance at end of year	61,001	61,990	65,979
Change in Plan Assets
Fair value of assets at beginning of year	93,475	86,085
Actual return on plan assets	7,024	10,307
Employer contributions		343
Defined Benefit Plan Refund to Employer	(393)
Employee contributions	1,386	2,122
Benefits Paid	(3,604)	(5,382)
Fair value of assets at end of year	97,888	93,475	86,085
Funded status	36,887	31,485
Amounts recognized in the balance sheet
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	36,887	31,485
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	(4,109)	(5,884)
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	4,254	1,355
Defined Benefit Plan Regulatory Liability Before Tax	(8,363)
Amounts recognized as AOCI (before tax)
Prior service cost	0	0
Net loss	0	0
Accumulated other comprehensive income (before taxes)	0	0
Entergy Mississippi [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	510,109	471,510
Service cost	9,070	8,060
Interest cost	10,446	12,922
Actuarial (gain)/loss	(14,831)	62,564
Benefits Paid	(65,936)	(44,947)
Balance at end of year	448,858	510,109	471,510
Change in Plan Assets
Fair value of assets at beginning of year	371,394	354,928
Actual return on plan assets	37,251	48,812
Employer contributions	13,715	12,601
Benefits Paid	(65,936)	(44,947)
Fair value of assets at end of year	356,424	371,394	354,928
Funded status	(92,434)	(138,715)
Amounts recognized in the balance sheet
Non-current liabilities	(92,434)	(138,715)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(173,511)	(239,904)
Amounts recognized as AOCI (before tax)
Net loss	0	0
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	31,707	38,460
Service cost	437	445	367
Interest cost	521	784	1,581
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(5,493)
Actuarial (gain)/loss	988	(91)
Employee contributions	403	1,123
Benefits Paid	(2,194)	(3,530)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	4	9
Balance at end of year	31,866	31,707	38,460
Change in Plan Assets
Fair value of assets at beginning of year	102,734	93,858
Actual return on plan assets	10,068	10,642
Employer contributions	126	641
Employee contributions	403	1,123
Benefits Paid	(2,194)	(3,530)
Fair value of assets at end of year	111,137	102,734	93,858
Funded status	79,271	71,027
Amounts recognized in the balance sheet
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	79,271	71,027
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	(3,814)	(4,730)
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	16,003	13,385
Defined Benefit Plan Regulatory Liability Before Tax	(19,817)	(18,115)
Amounts recognized as AOCI (before tax)
Prior service cost	0	0
Net loss	0	0
Accumulated other comprehensive income (before taxes)	0	0
Entergy New Orleans [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	220,287	206,962
Service cost	3,038	2,654
Interest cost	4,392	5,825
Actuarial (gain)/loss	(9,118)	20,535
Benefits Paid	(23,219)	(15,689)
Balance at end of year	195,380	220,287	206,962
Change in Plan Assets
Fair value of assets at beginning of year	172,551	160,777
Actual return on plan assets	17,639	22,896
Employer contributions	5,395	4,567
Benefits Paid	(23,219)	(15,689)
Fair value of assets at end of year	172,366	172,551	160,777
Funded status	(23,014)	(47,736)
Amounts recognized in the balance sheet
Non-current liabilities	(23,014)	(47,736)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(62,805)	(91,991)
Amounts recognized as AOCI (before tax)
Net loss	0	0
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	74,233	94,742
Service cost	1,384	1,219	943
Interest cost	1,269	2,008	3,415
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,776)	(22,441)
Actuarial (gain)/loss	4,270	5,952
Employee contributions	1,491	2,456
Benefits Paid	(6,923)	(9,721)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	13	18
Balance at end of year	71,961	74,233	94,742
Change in Plan Assets
Fair value of assets at beginning of year	174,096	161,810
Actual return on plan assets	13,523	18,861
Employer contributions	98	690
Employee contributions	1,491	2,456
Benefits Paid	(6,923)	(9,721)
Fair value of assets at end of year	182,285	174,096	161,810
Funded status	110,324	99,863
Amounts recognized in the balance sheet
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	110,324	99,863
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	(20,532)	(20,498)
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(2,571)	(2,030)
Defined Benefit Plan Regulatory Liability Before Tax	(17,961)
Amounts recognized as AOCI (before tax)
Prior service cost	0	0
Net loss	0	0
Accumulated other comprehensive income (before taxes)	0	0
Entergy Texas [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	410,664	396,764
Service cost	6,921	6,116
Interest cost	8,381	10,731
Actuarial (gain)/loss	(3,971)	37,579
Benefits Paid	(50,193)	(40,526)
Balance at end of year	371,802	410,664	396,764
Change in Plan Assets
Fair value of assets at beginning of year	349,748	339,126
Actual return on plan assets	35,405	46,151
Employer contributions	6,955	4,997
Benefits Paid	(50,193)	(40,526)
Fair value of assets at end of year	341,915	349,748	339,126
Funded status	(29,887)	(60,916)
Amounts recognized in the balance sheet
Non-current liabilities	(29,887)	(60,916)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(113,790)	(156,480)
Amounts recognized as AOCI (before tax)
Net loss	0	0
System Energy [Member]
Amounts recognized in the balance sheet
Non-current liabilities	(76,104)	(125,412)
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Change in APBO
Balance at beginning of year	47,701	47,348
Service cost	1,340	1,254	973
Interest cost	878	1,130	1,902
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	69	(1,963)
Actuarial (gain)/loss	1,289	3,025
Employee contributions	1,353	1,732
Benefits Paid	(4,769)	(4,851)
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received (Deprecated 2017-01-31)	14	26
Balance at end of year	47,875	47,701	47,348
Change in Plan Assets
Fair value of assets at beginning of year	52,619	48,471
Actual return on plan assets	4,235	5,925
Employer contributions	1,212	1,342
Employee contributions	1,353	1,732
Benefits Paid	(4,769)	(4,851)
Fair value of assets at end of year	54,650	52,619	48,471
Funded status	6,775	4,918
Amounts recognized in the balance sheet
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	6,775	4,918
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan Regulatory Asset Net Prior Service Cost (Credit) Before Tax	(1,249)	(1,754)
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(2,967)	(2,818)
Amounts recognized as AOCI (before tax)
Prior service cost	0	0
Net loss	0	0
Accumulated other comprehensive income (before taxes)	0	0
System Energy [Member] | Qualified Pension Obligations [Member]
Change in APBO
Balance at beginning of year	441,148	393,607
Service cost	8,851	7,883
Interest cost	9,087	11,006
Actuarial (gain)/loss	(14,746)	57,574
Benefits Paid	(49,546)	(28,922)
Balance at end of year	394,794	441,148	393,607
Change in Plan Assets
Fair value of assets at beginning of year	310,818	282,668
Actual return on plan assets	32,125	40,927
Employer contributions	18,663	16,145
Benefits Paid	(49,546)	(28,922)
Fair value of assets at end of year	312,060	310,818	$ 282,668
Funded status	(82,734)	(130,330)
Amounts recognized in the balance sheet
Non-current liabilities	(82,734)	(130,330)
Amounts recognized as a regulatory asset (before tax) [Abstract]
Defined Benefit Plan, Regulatory Asset, Gain (Loss) before Tax	(153,782)	(212,062)
Amounts recognized as AOCI (before tax)
Net loss	$ 0	$ 0

Retirement, Other Postretirem_6

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Projected Benefit Obligations (Details) - Non-Qualified Pension Plans [Member] - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Projected Benefit Obligation	$ 181,600	$ 182,400
Accumulated pension benefit obligation	165,500	161,300
Entergy Arkansas [Member]
Projected Benefit Obligation	2,875	3,197
Accumulated pension benefit obligation	2,482	2,626
Entergy Louisiana [Member]
Projected Benefit Obligation	1,469	1,965
Accumulated pension benefit obligation	1,445	1,802
Entergy Mississippi [Member]
Projected Benefit Obligation	3,708	3,852
Accumulated pension benefit obligation	3,377	3,345
Entergy New Orleans [Member]
Projected Benefit Obligation	1,069	247
Accumulated pension benefit obligation	738	240
Entergy Texas [Member]
Projected Benefit Obligation	7,462	8,475
Accumulated pension benefit obligation	$ 7,355	$ 7,949

Retirement, Other Postretirem_7

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Accumulated Benefit Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Qualified Pension Plans [Member]
Accumulated pension benefit obligation	$ 7,800,000	$ 8,400,000
Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	165,500	161,300
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,168)	(128,837)
Entergy Arkansas [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	1,463,966	1,617,858
Entergy Arkansas [Member] | Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	2,482	2,626
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(85)	12,320
Defined Benefit Plan Refund to Employer	(767)
Entergy Louisiana [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	1,574,273	1,753,980
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	1,445	1,802
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	357	(23,508)
Entergy Mississippi [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	407,851	466,497
Entergy Mississippi [Member] | Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	3,377	3,345
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(4,428)
Defined Benefit Plan Refund to Employer	(393)
Entergy New Orleans [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	178,010	201,159
Entergy New Orleans [Member] | Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	738	240
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(5,493)
Entergy Texas [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	342,441	379,050
Entergy Texas [Member] | Non-Qualified Pension Plans [Member]
Accumulated pension benefit obligation	7,355	7,949
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,776)	(22,441)
System Energy [Member] | Qualified Pension Plans [Member]
Accumulated pension benefit obligation	366,920	410,296
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	$ 69	$ (1,963)

Retirement, Other Postretirem_8

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Schedule Of Amounts Recorded On The Balance Sheet (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Current liabilities	$ (68,336)	$ (61,815)
Non-current liabilities	(1,949,325)	(2,853,013)
Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	165,500	161,300
Accumulated other comprehensive income (before taxes)	17,000	16,700
Other Postretirement Benefits Plan [Member]
Employee contributions	22,023	37,176
Current liabilities	(42,000)	(38,963)
Non-current liabilities	(376,363)	(404,246)
Accumulated other comprehensive income (before taxes)	(34,350)	(59,216)
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,168)	(128,837)
Entergy Arkansas [Member]
Non-current liabilities	(185,789)	(361,682)
Entergy Arkansas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	2,482	2,626
Current liabilities	(248)	(218)
Non-current liabilities	(2,627)	(2,979)
Total funded status	(2,875)	(3,197)
Assets for Plan Benefits, Defined Benefit Plan	1,059	1,535
Accumulated other comprehensive income (before taxes)	0	0
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	5,637	7,792
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	94,312	94,823
Accumulated other comprehensive income (before taxes)	0	0
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(85)	12,320
Entergy Louisiana [Member]
Non-current liabilities	(528,213)	(692,728)
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	1,445	1,802
Current liabilities	(186)	(193)
Non-current liabilities	(1,283)	(1,772)
Total funded status	(1,469)	(1,965)
Assets for Plan Benefits, Defined Benefit Plan	233	424
Accumulated other comprehensive income (before taxes)	10	18
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	5,186	8,269
Current liabilities	(15,839)	(15,580)
Non-current liabilities	(237,192)	(239,991)
Accumulated other comprehensive income (before taxes)	(34,518)	(37,792)
Defined Benefit Plan Regulatory Asset Before Tax	0	0
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	357	(23,508)
Entergy Mississippi [Member]
Non-current liabilities	(59,065)	(110,901)
Entergy Mississippi [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	3,377	3,345
Current liabilities	(190)	(181)
Non-current liabilities	(3,518)	(3,671)
Total funded status	(3,708)	(3,852)
Assets for Plan Benefits, Defined Benefit Plan	1,368	1,757
Accumulated other comprehensive income (before taxes)	0	0
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	1,386	2,122
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	36,887	31,485
Accumulated other comprehensive income (before taxes)	0	0
Defined Benefit Plan Regulatory Asset Before Tax		(7,239)
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(4,428)
Entergy New Orleans [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	738	240
Current liabilities	(31)	(17)
Non-current liabilities	(1,039)	(230)
Total funded status	(1,070)	(247)
Assets for Plan Benefits, Defined Benefit Plan	251
Liability, Defined Benefit Pension Plan		(558)
Accumulated other comprehensive income (before taxes)	0	0
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	403	1,123
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	79,271	71,027
Accumulated other comprehensive income (before taxes)	0	0
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	(5,493)
Entergy Texas [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan, Accumulated Benefit Obligation	7,355	7,949
Current liabilities	(3,080)	(633)
Non-current liabilities	(4,382)	(7,842)
Total funded status	(7,462)	(8,475)
Assets for Plan Benefits, Defined Benefit Plan		147
Liability, Defined Benefit Pension Plan	(706)
Accumulated other comprehensive income (before taxes)	0	0
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	1,491	2,456
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	110,324	99,863
Accumulated other comprehensive income (before taxes)	0	0
Defined Benefit Plan Regulatory Asset Before Tax		(18,468)
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	(3,776)	(22,441)
System Energy [Member]
Non-current liabilities	(76,104)	(125,412)
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Employee contributions	1,353	1,732
Current liabilities	0	0
Assets for Plan Benefits, Defined Benefit Plan	6,775	4,918
Accumulated other comprehensive income (before taxes)	0	0
Defined Benefit Plan Regulatory Asset Before Tax	(1,718)	(1,064)
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	$ 69	$ (1,963)

Retirement, Other Postretirem_9

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Retirement, Other Postretirement Benefits, And Defined Contribution Plans (Reclassification Out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 20,947	$ 20,769
Amortization of loss	(88,838)	(110,185)
Settlement loss	(16,379)	(243)
Total	(84,270)	(89,659)
Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(204)	(231)
Amortization of loss	(2,194)	(3,326)
Settlement loss	(4,378)	0
Total	(6,776)	(3,557)
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(84,661)	(105,853)
Settlement loss	(12,001)	(243)
Total	(96,662)	(106,096)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	21,151	21,000
Amortization of loss	(1,983)	(1,006)
Settlement loss	0	0
Total	19,168	19,994
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	4,920	6,179
Amortization of loss	(2,322)	(1,557)
Settlement loss	(2,484)	(243)
Total	114	4,379
Entergy Louisiana [Member] | Non-Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(5)	(3)
Settlement loss	(6)	0
Total	(11)	(3)
Entergy Louisiana [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0
Amortization of loss	(2,681)	(2,001)
Settlement loss	(2,478)	(243)
Total	(5,159)	(2,244)
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	4,920	6,179
Amortization of loss	364	447
Settlement loss	0	0
Total	$ 5,284	$ 6,626

Retirement, Other Postretire_10

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Plan Assets, Asset Allocations Targets (Details)	Dec. 31, 2021	Dec. 31, 2020
Qualified Pension Plans [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	39.00%
Postretirement Asset Allocation	40.00%	38.00%
Qualified Pension Plans [Member] | Domestic Equity Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	32.00%
Qualified Pension Plans [Member] | Domestic Equity Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	46.00%
Qualified Pension Plans [Member] | International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	19.00%
Postretirement Asset Allocation	20.00%	19.00%
Qualified Pension Plans [Member] | International Equity Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	15.00%
Qualified Pension Plans [Member] | International Equity Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	23.00%
Qualified Pension Plans [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	42.00%
Postretirement Asset Allocation	40.00%	42.00%
Qualified Pension Plans [Member] | Fixed Income Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	39.00%
Qualified Pension Plans [Member] | Fixed Income Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	45.00%
Qualified Pension Plans [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Postretirement Asset Allocation	0.00%	1.00%
Qualified Pension Plans [Member] | Other Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Qualified Pension Plans [Member] | Other Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	10.00%
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	25.00%
Postretirement Asset Allocation	28.00%	29.00%
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	20.00%
Other Postretirement Benefits Plan [Member] | Domestic Equity Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	30.00%
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	17.00%
Postretirement Asset Allocation	17.00%	18.00%
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	12.00%
Other Postretirement Benefits Plan [Member] | International Equity Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	22.00%
Other Postretirement Benefits Plan [Member] | Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	58.00%
Postretirement Asset Allocation	55.00%	53.00%
Other Postretirement Benefits Plan [Member] | Fixed Income Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	53.00%
Other Postretirement Benefits Plan [Member] | Fixed Income Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	63.00%
Other Postretirement Benefits Plan [Member] | Other Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Postretirement Asset Allocation	0.00%	0.00%
Other Postretirement Benefits Plan [Member] | Other Securities [Member] | Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	0.00%
Other Postretirement Benefits Plan [Member] | Other Securities [Member] | Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Target	5.00%

Retirement, Other Postretire_11

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Investments Held For Qualified Pension And Other Postretirement Plans Measured At Fair Value (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Cash	$ 123,153	$ 2,316
Other pending transactions	11,125	(29,121)
Less: Other postretirement assets included in total investments	(79,360)	(76,033)
Defined Benefit Plan, Plan Assets, Amount	6,993,110	6,854,426
Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	16,231	15,756
Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	1,001,169	1,031,213
Qualified Pension Plans [Member] | Defined Benefit Plan, Common Collective Trust
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	3,123,111	2,958,767
Qualified Pension Plans [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	627,148	731,319
Qualified Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	966,616	1,029,370
Qualified Pension Plans [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	1,129,070	1,128,107
Qualified Pension Plans [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	68,886	56,479
Qualified Pension Plans [Member] | Other Contract
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	5,961	6,253
Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	6,938,192	6,957,264
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Other pending transactions	(25,897)	(21,931)
Plus: Other postretirement assets included in the investments of the qualified pension trust	79,360	76,033
Defined Benefit Plan, Plan Assets, Amount	771,319	737,866	$ 686,262
Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Common Collective Trust
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	312,594	315,191
Other Postretirement Benefits Plan [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	152,191	144,102
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	152,562	147,287
Other Postretirement Benefits Plan [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	28,450	16,965
Other Postretirement Benefits Plan [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	72,059	60,219
Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	717,856	683,764
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	16,231	15,756
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	1,001,169	1,031,213
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	92,347	81,800
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	156
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Other Contract
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 1 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	1,109,747	1,128,925
Fair Value Inputs Level 1 [Member] | Other Postretirement Benefits Plan [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	62,240	46,498
Fair Value Inputs Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	28,450	16,965
Fair Value Inputs Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 1 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	90,690	63,463
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	627,148	731,319
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	966,616	1,029,370
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	3,004	3,076
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	68,886	56,323
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Other Contract
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	5,961	6,253
Fair Value Inputs Level 2 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	1,671,615	1,826,341
Fair Value Inputs Level 2 [Member] | Other Postretirement Benefits Plan [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	89,951	97,604
Fair Value Inputs Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	152,562	147,287
Fair Value Inputs Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	72,059	60,219
Fair Value Inputs Level 2 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	314,572	305,110
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, US [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan, Equity Securities, Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Other Contract
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Qualified Pension Plans [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Other Postretirement Benefits Plan [Member] | U.S. Government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Registered Investment Company
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Other Debt Obligations
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	0	0
Fair Value Inputs Level 3 [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan Total Plan Assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Amount	$ 0	$ 0

Retirement, Other Postretire_12

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Estimated Future Benefit Payments (Details) $ in Thousands	Dec. 31, 2021USD ($)
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	$ 70
Estimated Future Medicare Subsidy Receipts, Year Two	27
Estimated Future Medicare Subsidy Receipts, Year Three	34
Estimated Future Medicare Subsidy Receipts, Year Four	34
Estimated Future Medicare Subsidy Receipts, Year Five	39
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	222
Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	550,204
Estimated Future Benefits Payments, Year Two	542,753
Estimated Future Benefits Payments, Year Three	549,913
Estimated Future Benefits Payments, Year Four	530,406
Estimated Future Benefits Payments, Year Five	525,278
Estimated Future Benefits Payments, Year Six - Year Ten	2,527,735
Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	26,336
Estimated Future Benefits Payments, Year Two	24,710
Estimated Future Benefits Payments, Year Three	21,230
Estimated Future Benefits Payments, Year Four	36,210
Estimated Future Benefits Payments, Year Five	14,377
Estimated Future Benefits Payments, Year Six - Year Ten	52,967
Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	72,400
Estimated Future Benefits Payments, Year Two	72,220
Estimated Future Benefits Payments, Year Three	71,506
Estimated Future Benefits Payments, Year Four	70,148
Estimated Future Benefits Payments, Year Five	68,744
Estimated Future Benefits Payments, Year Six - Year Ten	328,634
Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	35
Estimated Future Medicare Subsidy Receipts, Year Two	3
Estimated Future Medicare Subsidy Receipts, Year Three	4
Estimated Future Medicare Subsidy Receipts, Year Four	4
Estimated Future Medicare Subsidy Receipts, Year Five	5
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	27
Entergy Arkansas [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	107,542
Estimated Future Benefits Payments, Year Two	104,328
Estimated Future Benefits Payments, Year Three	104,606
Estimated Future Benefits Payments, Year Four	102,411
Estimated Future Benefits Payments, Year Five	101,144
Estimated Future Benefits Payments, Year Six - Year Ten	487,637
Entergy Arkansas [Member] | Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	248
Estimated Future Benefits Payments, Year Two	383
Estimated Future Benefits Payments, Year Three	324
Estimated Future Benefits Payments, Year Four	689
Estimated Future Benefits Payments, Year Five	143
Estimated Future Benefits Payments, Year Six - Year Ten	878
Entergy Arkansas [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	14,228
Estimated Future Benefits Payments, Year Two	13,652
Estimated Future Benefits Payments, Year Three	13,392
Estimated Future Benefits Payments, Year Four	13,021
Estimated Future Benefits Payments, Year Five	12,717
Estimated Future Benefits Payments, Year Six - Year Ten	61,153
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	6
Estimated Future Medicare Subsidy Receipts, Year Two	5
Estimated Future Medicare Subsidy Receipts, Year Three	7
Estimated Future Medicare Subsidy Receipts, Year Four	8
Estimated Future Medicare Subsidy Receipts, Year Five	7
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	51
Entergy Louisiana [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	120,365
Estimated Future Benefits Payments, Year Two	118,289
Estimated Future Benefits Payments, Year Three	117,416
Estimated Future Benefits Payments, Year Four	116,610
Estimated Future Benefits Payments, Year Five	114,232
Estimated Future Benefits Payments, Year Six - Year Ten	534,665
Entergy Louisiana [Member] | Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	186
Estimated Future Benefits Payments, Year Two	172
Estimated Future Benefits Payments, Year Three	159
Estimated Future Benefits Payments, Year Four	146
Estimated Future Benefits Payments, Year Five	133
Estimated Future Benefits Payments, Year Six - Year Ten	503
Entergy Louisiana [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	15,845
Estimated Future Benefits Payments, Year Two	15,766
Estimated Future Benefits Payments, Year Three	15,404
Estimated Future Benefits Payments, Year Four	15,182
Estimated Future Benefits Payments, Year Five	14,868
Estimated Future Benefits Payments, Year Six - Year Ten	70,094
Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	14
Estimated Future Medicare Subsidy Receipts, Year Two	15
Estimated Future Medicare Subsidy Receipts, Year Three	16
Estimated Future Medicare Subsidy Receipts, Year Four	17
Estimated Future Medicare Subsidy Receipts, Year Five	18
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	104
Entergy Mississippi [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	33,459
Estimated Future Benefits Payments, Year Two	33,055
Estimated Future Benefits Payments, Year Three	32,711
Estimated Future Benefits Payments, Year Four	31,838
Estimated Future Benefits Payments, Year Five	31,708
Estimated Future Benefits Payments, Year Six - Year Ten	143,052
Entergy Mississippi [Member] | Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	190
Estimated Future Benefits Payments, Year Two	422
Estimated Future Benefits Payments, Year Three	504
Estimated Future Benefits Payments, Year Four	486
Estimated Future Benefits Payments, Year Five	412
Estimated Future Benefits Payments, Year Six - Year Ten	1,927
Entergy Mississippi [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	3,488
Estimated Future Benefits Payments, Year Two	3,550
Estimated Future Benefits Payments, Year Three	3,597
Estimated Future Benefits Payments, Year Four	3,657
Estimated Future Benefits Payments, Year Five	3,645
Estimated Future Benefits Payments, Year Six - Year Ten	18,095
Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	0
Estimated Future Medicare Subsidy Receipts, Year Two	0
Estimated Future Medicare Subsidy Receipts, Year Three	0
Estimated Future Medicare Subsidy Receipts, Year Four	0
Estimated Future Medicare Subsidy Receipts, Year Five	1
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	0
Entergy New Orleans [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	13,992
Estimated Future Benefits Payments, Year Two	13,677
Estimated Future Benefits Payments, Year Three	13,333
Estimated Future Benefits Payments, Year Four	13,146
Estimated Future Benefits Payments, Year Five	12,875
Estimated Future Benefits Payments, Year Six - Year Ten	58,299
Entergy New Orleans [Member] | Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	31
Estimated Future Benefits Payments, Year Two	82
Estimated Future Benefits Payments, Year Three	104
Estimated Future Benefits Payments, Year Four	135
Estimated Future Benefits Payments, Year Five	128
Estimated Future Benefits Payments, Year Six - Year Ten	782
Entergy New Orleans [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	2,449
Estimated Future Benefits Payments, Year Two	2,378
Estimated Future Benefits Payments, Year Three	2,288
Estimated Future Benefits Payments, Year Four	2,200
Estimated Future Benefits Payments, Year Five	2,096
Estimated Future Benefits Payments, Year Six - Year Ten	9,058
Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	0
Estimated Future Medicare Subsidy Receipts, Year Two	0
Estimated Future Medicare Subsidy Receipts, Year Three	0
Estimated Future Medicare Subsidy Receipts, Year Four	0
Estimated Future Medicare Subsidy Receipts, Year Five	0
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	0
Entergy Texas [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	31,134
Estimated Future Benefits Payments, Year Two	30,381
Estimated Future Benefits Payments, Year Three	28,661
Estimated Future Benefits Payments, Year Four	26,807
Estimated Future Benefits Payments, Year Five	26,983
Estimated Future Benefits Payments, Year Six - Year Ten	114,747
Entergy Texas [Member] | Non-Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	3,080
Estimated Future Benefits Payments, Year Two	441
Estimated Future Benefits Payments, Year Three	420
Estimated Future Benefits Payments, Year Four	398
Estimated Future Benefits Payments, Year Five	428
Estimated Future Benefits Payments, Year Six - Year Ten	1,677
Entergy Texas [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	5,061
Estimated Future Benefits Payments, Year Two	4,998
Estimated Future Benefits Payments, Year Three	4,824
Estimated Future Benefits Payments, Year Four	4,686
Estimated Future Benefits Payments, Year Five	4,458
Estimated Future Benefits Payments, Year Six - Year Ten	20,932
System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Medicare Subsidy Receipts, Year One	1
Estimated Future Medicare Subsidy Receipts, Year Two	1
Estimated Future Medicare Subsidy Receipts, Year Three	1
Estimated Future Medicare Subsidy Receipts, Year Four	0
Estimated Future Medicare Subsidy Receipts, Year Five	1
Estimated Future Medicare Subsidy Receipts, Year Six - Year Ten	4
System Energy [Member] | Qualified Pension Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	26,953
Estimated Future Benefits Payments, Year Two	25,985
Estimated Future Benefits Payments, Year Three	26,155
Estimated Future Benefits Payments, Year Four	25,203
Estimated Future Benefits Payments, Year Five	24,939
Estimated Future Benefits Payments, Year Six - Year Ten	123,220
System Energy [Member] | Other Postretirement Benefit Obligations [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated Future Benefits Payments, Year One	2,828
Estimated Future Benefits Payments, Year Two	2,774
Estimated Future Benefits Payments, Year Three	2,668
Estimated Future Benefits Payments, Year Four	2,617
Estimated Future Benefits Payments, Year Five	2,511
Estimated Future Benefits Payments, Year Six - Year Ten	$ 12,474

Retirement, Other Postretire_13

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Expected Employer Contributions (Details) $ in Thousands	Dec. 31, 2021USD ($)
Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	$ 42,800
Entergy Arkansas [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	40,840
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	517
Entergy Louisiana [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	22,917
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	15,845
Entergy Mississippi [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	12,852
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	130
Entergy New Orleans [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	922
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	175
Entergy Texas [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	1,924
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	66
System Energy [Member] | Pension Plans, Defined Benefit [Member]
Change in Plan Assets
Expected Employer Contributions	12,760
System Energy [Member] | Other Postretirement Benefits Plan [Member]
Change in Plan Assets
Expected Employer Contributions	$ 22

Retirement, Other Postretire_14

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Actuarial Assumptions Used In Determining Pension And Other Postretirement Benefit Obligation (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Weighted-Average Interest Crediting Rate	2.60%	2.60%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.75%	4.75%
Pre-65 Retirees [Member]
Defined Benefit Plan Disclosure [Line Items]
Assumed health care cost trend rate	5.65%	5.87%
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate	2032	2030
Post - 65 Retirees [Member]
Defined Benefit Plan Disclosure [Line Items]
Assumed health care cost trend rate	5.90%	6.31%
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate	2032	2028
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	2.94%	2.62%
Pension Plans, Defined Benefit [Member] | Nonqualified Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	2.11%	1.61%
Pension Plans, Defined Benefit [Member] | Qualified Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Blended weighted-average discount rate	0.00031%	0.00028%
Minimum [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average rate of increase in future compensation levels	0.0004%	0.0004%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Qualified Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average discount rate	0.0003%	0.00026%
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average rate of increase in future compensation levels	0.00044%	0.00044%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Qualified Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted-average discount rate	0.00031%	0.00028%

Retirement, Other Postretire_15

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Actuarial Assumptions Used In Determining Net Periodic And Other Postretirement Benefit Obligation (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Weighted-average rate of increase in future compensation levels			3.98%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.75%	4.75%	4.75%
Pre-65 Retirees [Member]
Defined Benefit Plan, Health Care Cost Trend Rate, Net Periodic Pension and Other Postretirement Benefit Costs	5.87%	6.13%	6.59%
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate	2030	2027	2027
Post - 65 Retirees [Member]
Defined Benefit Plan, Health Care Cost Trend Rate, Net Periodic Pension and Other Postretirement Benefit Costs	6.31%	6.25%	7.15%
Defined Benefit Plan, Year Health Care Cost Trend Rate Reaches Ultimate Trend Rate	2028	2027	2026
Other Postretirement Benefits Plan [Member] | Measurement Input Discount Rate Service Costs
Weighted-average discount rate	2.98%	3.27%	4.62%
Other Postretirement Benefits Plan [Member] | Measurement Input Discount Rate Interest Costs
Weighted-average discount rate	1.86%	2.41%	4.01%
Other Postretirement Benefits Plan [Member] | Taxable [Member]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	5.00%	5.25%	5.50%
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	6.75%	7.00%	7.25%
Pension Plans, Defined Benefit [Member] | Qualified Plan [Member] | Measurement Input Discount Rate Service Costs
Weighted-average discount rate	2.81%	3.42%	4.57%
Pension Plans, Defined Benefit [Member] | Qualified Plan [Member] | Measurement Input Discount Rate Interest Costs
Weighted-average discount rate	2.08%	2.99%	4.15%
Pension Plans, Defined Benefit [Member] | Nonqualified Plan [Member] | Measurement Input Discount Rate Service Costs
Weighted-average discount rate	1.48%	2.71%	3.94%
Pension Plans, Defined Benefit [Member] | Nonqualified Plan [Member] | Measurement Input Discount Rate Interest Costs
Weighted-average discount rate	2.14%	2.25%	3.46%
Minimum [Member]
Weighted-average rate of increase in future compensation levels	0.0398%	3.98%
Minimum [Member] | Other Postretirement Benefits Plan [Member] | Other Postretirement Non Taxable Assets [Member]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	0.06%	0.00063%	0.065%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Qualified Plan [Member]
Weighted-average discount rate	0.0003%	0.00026%
Maximum [Member]
Weighted-average rate of increase in future compensation levels	0.044%	4.40%
Maximum [Member] | Other Postretirement Benefits Plan [Member] | Other Postretirement Non Taxable Assets [Member]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	0.0675%	0.0725%	0.075%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Qualified Plan [Member]
Weighted-average discount rate	0.00031%	0.00028%

Retirement, Other Postretire_16

Retirement, Other Postretirement Benefits, And Defined Contribution Plans Contributions To Defined Contribution Plans (Details) - Defined Contribution Plans [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Entergy Arkansas [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 4,820	$ 4,515	$ 4,111
Entergy Louisiana [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	6,678	6,518	5,641
Entergy Mississippi [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	3,045	2,863	2,424
Entergy New Orleans [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	1,140	1,115	882
Entergy Texas [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 2,699	$ 2,596	$ 2,136

Stock-Based Compensation (Narra

Stock-Based Compensation (Narrative) (Details) - USD ($)	1 Months Ended			12 Months Ended
	Jan. 31, 2021	Jan. 31, 2020	Jan. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
2019 Omnibus Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for grant				4,711,095
Number of shares authorized				7,300,000
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value				$ 5,000,000	$ 5,000,000	$ 5,000,000
Expiration of stock-based awards				10 years
Percentage of after tax net profit to be retained by the executive officer to achieve ownership position				75.00%
Weighted-average grant-date fair value of options granted (in USD per share)				$ 12.27	$ 11.45	$ 8.32
Total intrinsic value of options exercised				$ 2,000,000	$ 26,000,000	$ 29,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value				71,110,949
Cost related to non-vested stock options outstanding not yet recognized				$ 7,000,000
Recognition period				1 year 8 months 19 days
Proceeds from Stock Options Exercised				$ 6,000,000
Employee Service Share-based Compensation, Tax Benefit Realized from Exercise of Stock Options (Deprecated 2017-01-31)				$ 500,000
Out of the money stock options of total stock options outstanding				501,316
Out of the money stock options of total stock options outstanding				501,316
Incentive Stock Options [Member] | 2016-2018 Long-Term Performance Unit Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average grant-date fair value of options granted (in USD per share)			$ 86.03
Long term incentive plan awards (in shares)			226,208
Incentive Stock Options [Member] | 2017-2019 Long-Term Performance Unit Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average grant-date fair value of options granted (in USD per share)		$ 126.31
Long term incentive plan awards (in shares)		423,184
Incentive Stock Options [Member] | 2018-2020 Long-Term Performance Unit Program
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average grant-date fair value of options granted (in USD per share)	$ 95.12
Long term incentive plan awards (in shares)	235,983
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Grants, Fair Value				$ 40,000,000	44,000,000	34,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value				32,000,000	27,000,000	25,000,000
Restricted Awards [Member] | 2019 Omnibus Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for grant	392,383
Weighted-average grant-date fair value of options granted (in USD per share)	$ 95.87
Long Term Incentive Plan [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, Grants, Fair Value				$ 32,000,000	40,000,000	23,000,000
Percent of performance measure based on relative total shareholder return				80.00%
Percent of performance measure based on cumulative adjusted metric				20.00%
Long term incentive plan awards (in shares)	203,983
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Grants, Fair Value				$ 4,000,000	2,000,000	3,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value				$ 3,000,000	$ 4,000,000	$ 5,900,000
Average award vesting period				35 months
Number of unvested restricted units expected to vest				88,648
Period expected for vesting unvested restricted units				18 months
Performance measure based on relative total shareholder return [Member] | Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 110.74
Performance measure based on cumulative adjusted earnings per share metric [Member] | Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 95.87

Stock-Based Compensation (Sched

Stock-Based Compensation (Schedule Of Financial Information Of Options) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value	$ 5	$ 5	$ 5
Compensation expense included in Entergy's Consolidated Net Income for the year	4.2	3.9	3.8
Tax benefit (expense) recognized in Entergy's Consolidated Net Income for the year	1.1	1	1
Compensation cost capitalized as part of fixed assets and inventory	1.5	1.5	1.4
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value	32	27	25
Compensation expense included in Entergy's Consolidated Net Income for the year	24.7	23.1	20.2
Tax benefit (expense) recognized in Entergy's Consolidated Net Income for the year	6.3	5.9	5.1
Compensation cost capitalized as part of fixed assets and inventory	9.3	8.5	7.1
Long-Term Incentive Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense included in Entergy's Consolidated Net Income for the year	14.5	12.6	11.1
Tax benefit (expense) recognized in Entergy's Consolidated Net Income for the year	3.7	3.2	2.8
Compensation cost capitalized as part of fixed assets and inventory	5.8	4.9	4
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value	3	4	5.9
Compensation expense included in Entergy's Consolidated Net Income for the year	1.9	2	2.2
Tax benefit (expense) recognized in Entergy's Consolidated Net Income for the year	0.5	0.5	0.6
Compensation cost capitalized as part of fixed assets and inventory	$ 0.7	$ 0.9	$ 0.9

Stock-Based Compensation (Stock

Stock-Based Compensation (Stock Option Weighted-Average Assumptions Used In Determining Fair Values) (Details) - Employee Stock Option [Member] - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock price volatility	23.93%	17.16%	17.23%
Expected term	6 years 11 months 4 days	7 years 14 days	7 years 3 months 25 days
Risk-free interest rate	0.74%	1.49%	2.50%
Dividend yield	4.00%	4.00%	4.50%
Dividend payment per share	$ 3.86	$ 3.74	$ 3.66

Stock-Based Compensation (Summa

Stock-Based Compensation (Summary Of Stock Option Activity) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of options outstanding, Beginning balance	2,399,379
Options outstanding, Weighted-average exercise price, Beginning balance (in usd per share)	$ 89.63
Number of options granted	508,704
Options granted, Weighted-average exercise price (in usd per share)	$ 95.87
Number of options exercised	(72,138)
Options exercised, Weighted-average exercise price (in usd per share)	$ 80.54
Number of Options forfeited/expired	(16,301)
Options forfeited/expired, Weighted-average exercise price (in usd per share)	$ 117.89
Number of options outstanding, Ending balance	2,819,644	2,399,379
Options outstanding, Weighted-average exercise price, Ending balance (in usd per share)	$ 90.82	$ 89.63
Weighted-Average Contractual Life, Options outstanding	6 years 4 months 2 days
Options exercisable, Number of Options	1,788,702
Options exercisable, Weighted-Average Exercise Price (in usd per share)	$ 81.91
Options exercisable, Aggregate intrinsic value (in usd per share)	$ 58,164,228
Weighted-Average Contractual Life, Options exercisable	5 years 1 month 28 days
Weighted-average grant-date fair value of options granted (in USD per share)	$ 12.27	$ 11.45	$ 8.32
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of options outstanding, Beginning balance	648,498
Options outstanding, Weighted-average exercise price, Beginning balance (in usd per share)	$ 107.89
Number of options granted	419,095
Options granted, Weighted-average exercise price (in usd per share)	$ 96.45
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares	(323,698)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price	$ 99.28
Number of Options forfeited/expired	(58,540)
Options forfeited/expired, Weighted-average exercise price (in usd per share)	$ 108.57
Number of options outstanding, Ending balance	685,355	648,498
Options outstanding, Weighted-average exercise price, Ending balance (in usd per share)	$ 104.91	$ 107.89
Long-Term Incentive Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of options outstanding, Beginning balance	475,765
Options outstanding, Weighted-average exercise price, Beginning balance (in usd per share)	$ 110.82
Number of options granted	303,092
Options granted, Weighted-average exercise price (in usd per share)	$ 104.02
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares	(235,983)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price	$ 82.42
Number of Options forfeited/expired	(21,038)
Options forfeited/expired, Weighted-average exercise price (in usd per share)	$ 122.87
Number of options outstanding, Ending balance	521,836	475,765
Options outstanding, Weighted-average exercise price, Ending balance (in usd per share)	$ 119.23	$ 110.82
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of options outstanding, Beginning balance	86,175
Options outstanding, Weighted-average exercise price, Beginning balance (in usd per share)	$ 92.92
Number of options granted	39,478
Options granted, Weighted-average exercise price (in usd per share)	$ 105.06
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested, Number of Shares	(37,005)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price	$ 90.89
Number of options outstanding, Ending balance	88,648	86,175
Options outstanding, Weighted-average exercise price, Ending balance (in usd per share)	$ 99.18	$ 92.92

Stock-Based Compensation (Sum_2

Stock-Based Compensation (Summary Of Stock Options Outstanding Information) (Details) - Employee Stock Option [Member]	12 Months Ended
	Dec. 31, 2021$ / sharesshares
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price, minimum (in usd per share)	$ 51
Exercise Price, maximum (in usd per share)	$ 131.72
Number of Outstanding Options | shares	2,819,644
Weighted-Avg. Remaining Contractual Life-Yrs	6 years 4 months 2 days
Weighted-Avg. Exercise Price (in usd per share)	$ 90.82
Number of Exercisable Options | shares	1,788,702
Weighted-Avg. Exercise Price (in usd per share)	$ 81.91
Range Of Exercise Prices 2 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price, minimum (in usd per share)	65
Exercise Price, maximum (in usd per share)	$ 78.99
Number of Outstanding Options | shares	915,839
Weighted-Avg. Remaining Contractual Life-Yrs	5 years 2 months 8 days
Weighted-Avg. Exercise Price (in usd per share)	$ 73.80
Number of Exercisable Options | shares	915,839
Weighted-Avg. Exercise Price (in usd per share)	$ 73.80
Range Of Exercise Prices 3 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price, minimum (in usd per share)	79
Exercise Price, maximum (in usd per share)	$ 91.99
Number of Outstanding Options | shares	653,585
Weighted-Avg. Remaining Contractual Life-Yrs	6 years 2 months 15 days
Weighted-Avg. Exercise Price (in usd per share)	$ 89.35
Number of Exercisable Options | shares	465,577
Weighted-Avg. Exercise Price (in usd per share)	$ 89.41
Range Of Exercise Prices1 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price, minimum (in usd per share)	51
Exercise Price, maximum (in usd per share)	$ 64.99
Number of Outstanding Options | shares	240,200
Weighted-Avg. Remaining Contractual Life-Yrs	1 year 8 months 19 days
Weighted-Avg. Exercise Price (in usd per share)	$ 63.69
Number of Exercisable Options | shares	240,200
Weighted-Avg. Exercise Price (in usd per share)	$ 63.69
Range Of Exercise Prices4
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price, minimum (in usd per share)	92
Exercise Price, maximum (in usd per share)	$ 131.72
Number of Outstanding Options | shares	1,010,020
Weighted-Avg. Remaining Contractual Life-Yrs	8 years 6 months 29 days
Weighted-Avg. Exercise Price (in usd per share)	$ 113.66
Number of Exercisable Options | shares	167,086
Weighted-Avg. Exercise Price (in usd per share)	$ 131.72

Business Segment Information Na

Business Segment Information Narrative (Details) - USD ($) $ in Thousands	1 Months Ended		12 Months Ended
	May 31, 2021	Aug. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2022	Dec. 31, 2018
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges			$ 263,599	$ 26,379	$ 226,678
Reduction in deferred income tax expense				230,000
Deferred Income Taxes and Tax Credits			248,719	(131,114)	193,950
Utility [Member]
Segment Reporting Information [Line Items]
Reduction in deferred income tax expense				396,000
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring costs incurred, pre-tax			13,000	71,000	91,000
Asset Write-Offs, Impairments, And Related Charges			264,000	19,000	290,000
Restructuring Reserve			37,000	159,000	143,000		$ 193,000
Deferred Income Taxes and Tax Credits				105,000
Entergy Wholesale Commodities [Member] | Pilgrim [Member]
Segment Reporting Information [Line Items]
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		$ 190,000
Reduction to income tax expense		$ 156,000
Reduction in income tax expense due to internal restructuring					156,000
Asset impairment excluding loss from sale of assets					100,000
Impairment of Long-Lived Assets Held-For-Use, Net of Tax					79,000
Entergy Wholesale Commodities [Member] | Indian Point Energy Center
Segment Reporting Information [Line Items]
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property	$ 340,000
Reduction to income tax expense	$ 268,000
Parent & Other [Member]
Segment Reporting Information [Line Items]
Deferred Income Taxes and Tax Credits				61,000
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring costs incurred, pre-tax			12,000	71,000	91,000
Restructuring Reserve			$ 37,000	$ 145,000	$ 129,000		$ 179,000
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Reserve						$ 5,000

Business Segment Information Se

Business Segment Information Segment Financial Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Segment Financial Information
Interest expense	$ 834,694	$ 785,663	$ 742,425
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Consolidated net income	1,118,719	1,406,653	1,258,244
Total assets	59,454,242	58,239,212
Eliminations [Member]
Segment Financial Information
Operating revenues	(29)	(25)	(52)
Depreciation, amortization, & decommissioning	0	0	0
Interest and investment income	(141,880)	(159,943)	(182,589)
Interest expense	(14,258)	(32,350)	(54,995)
Income Tax Expense (Benefit)	0	0	0
Consolidated net income	(127,622)	(127,594)	(127,594)
Total assets	(2,083,226)	(2,053,951)	(2,502,733)
Cash paid for long-lived asset additions	0	0	0
Asset Write-Offs, Impairments, And Related Charges	0	0	0
Utility [Member]
Segment Financial Information
Operating revenues	11,044,674	9,170,714	9,583,985
Depreciation, amortization, & decommissioning	1,823,389	1,685,138	1,493,167
Interest and investment income	442,817	299,004	289,570
Interest expense	692,004	648,851	589,395
Income Tax Expense (Benefit)	264,209	(282,311)	19,634
Consolidated net income	1,488,487	1,816,354	1,425,643
Total assets	59,733,625	55,940,153	49,557,664
Cash paid for long-lived asset additions	6,409,855	5,102,322	4,527,045
Asset Write-Offs, Impairments, And Related Charges	0	0	0
Entergy Wholesale Commodities [Member]
Segment Financial Information
Operating revenues	698,164	942,869	1,294,719
Depreciation, amortization, & decommissioning	164,602	306,974	384,707
Interest and investment income	118,597	234,194	414,636
Interest expense	13,334	22,432	29,450
Income Tax Expense (Benefit)	(25,381)	104,937	(161,295)
Consolidated net income	(120,689)	(62,763)	148,870
Total assets	1,242,675	3,800,378	4,154,961
Cash paid for long-lived asset additions	12,100	54,455	104,300
Asset Write-Offs, Impairments, And Related Charges	263,625	26,623	290,027
All Other [Member]
Segment Financial Information
Operating revenues	87	78	21
Depreciation, amortization, & decommissioning	2,706	2,835	2,944
Interest and investment income	10,932	19,563	26,295
Interest expense	143,614	146,730	178,575
Income Tax Expense (Benefit)	(47,454)	55,868	(28,164)
Consolidated net income	(121,457)	(219,344)	(188,675)
Total assets	561,168	552,632	514,020
Cash paid for long-lived asset additions	157	84	160
Asset Write-Offs, Impairments, And Related Charges	0	0	0
Entergy Corporation Consolidated
Segment Financial Information
Operating revenues	11,742,896	10,113,636	10,878,673
Depreciation, amortization, & decommissioning	1,990,697	1,994,947	1,880,818
Interest and investment income	430,466	392,818	547,912
Interest expense	834,694	785,663	742,425
Income Tax Expense (Benefit)	191,374	(121,506)	(169,825)
Consolidated net income	1,118,719	1,406,653	1,258,244
Total assets	59,454,242	58,239,212	51,723,912
Cash paid for long-lived asset additions	6,422,112	5,156,861	4,631,505
Asset Write-Offs, Impairments, And Related Charges	$ 263,625	$ 26,623	$ 290,027

Business Segment Information _2

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - Entergy Wholesale Commodities [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Restructuring Cost and Reserve [Line Items]
Restructuring costs	$ 13	$ 71	$ 91
Paid in cash	135	55	141
Restructuring Reserve	37	159	143	$ 193
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring costs	12	71	91
Paid in cash	120	55	141
Restructuring Reserve	37	145	129	179
Economic Development Costs [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring costs	1	0	0
Paid in cash	15	0	0
Restructuring Reserve	$ 0	$ 14	$ 14	$ 14

Acquisitions, Dispositions, a_2

Acquisitions, Dispositions, and Impairment of Long-Lived Assets Narrative (Details)	1 Months Ended											3 Months Ended			12 Months Ended
	Jan. 31, 2022USD ($)	Dec. 31, 2021USD ($)MW	Jun. 30, 2021USD ($)MW	May 31, 2021USD ($)	Nov. 30, 2020USD ($)MW	Oct. 31, 2019USD ($)MW	Aug. 31, 2019USD ($)	Apr. 30, 2019	Jan. 31, 2019USD ($)	Jul. 31, 2018	Nov. 30, 2016	Dec. 31, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2022USD ($)	Dec. 31, 2021USD ($)$ / MWh	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	May 28, 2021USD ($)
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																$ 11,742,896,000	$ 10,113,636,000	$ 10,878,673,000
Proceeds from Sale of Productive Assets																17,421,000	0	28,932,000
Net Book Value		$ 64,263,250,000														64,263,250,000	59,696,443,000
Asset Retirement Obligation		4,757,100,000										$ 6,159,200,000				4,757,100,000	6,469,500,000	6,159,200,000
Decommissioning Fund Investments		5,514,016,000														5,514,016,000	7,253,215,000
Asset Write-Offs, Impairments, And Related Charges																263,599,000	26,379,000	226,678,000
Asset Impairment Charges																263,625,000	26,623,000	290,027,000
Decommissioning																306,411,000	381,861,000	400,802,000
Assets, Fair Value Disclosure		6,005,000,000														$ 6,005,000,000	9,122,000,000
Discontinued Operation, Tax Effect of Discontinued Operation													$ 29,000,000
Acquisitions And Dispositions																ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Arkansas [Member]
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																$ 2,338,590,000	2,084,494,000	2,259,594,000
Net Book Value		13,578,297,000														13,578,297,000	12,905,322,000
Asset Retirement Obligation		1,390,400,000										1,242,600,000				1,390,400,000	1,314,200,000	1,242,600,000
Decommissioning Fund Investments		1,438,416,000														1,438,416,000	1,273,921,000
Decommissioning																77,696,000	73,319,000	68,030,000
Assets, Fair Value Disclosure		1,445,500,000														$ 1,445,500,000	1,444,600,000
Acquisitions And Dispositions																ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy New Orleans [Member]
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																$ 768,852,000	633,841,000	686,223,000
Net Book Value		1,976,202,000														1,976,202,000	1,821,638,000
Asset Retirement Obligation		4,000,000										3,500,000				4,000,000	3,800,000	3,500,000
Assets, Fair Value Disclosure		44,900,000														44,900,000	86,500,000
Reduction to income tax expense																	8,000,000
Entergy Louisiana [Member]
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																5,068,448,000	4,069,862,000	4,285,175,000
Proceeds from Sale of Productive Assets																15,000,000	0	0
Net Book Value		28,055,038,000														28,055,038,000	25,619,789,000
Asset Retirement Obligation		1,653,200,000										1,497,300,000				1,653,200,000	1,573,300,000	1,497,300,000
Decommissioning Fund Investments		2,114,523,000														2,114,523,000	1,794,042,000
Decommissioning																68,575,000	65,225,000	59,346,000
Assets, Fair Value Disclosure		2,144,500,000														$ 2,144,500,000	2,528,900,000
Acquisitions And Dispositions																ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Mississippi [Member]
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																$ 1,406,346,000	1,247,854,000	1,323,043,000
Net Book Value		6,613,109,000														6,613,109,000	6,084,730,000
Asset Retirement Obligation		10,300,000										9,700,000				10,300,000	9,800,000	9,700,000
Assets, Fair Value Disclosure		96,800,000														$ 96,800,000	65,200,000
Acquisitions And Dispositions																ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Nuclear Generation Company [Member]
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property							$ 190,000,000
Decommissioning Trust Fair Values							1,030,000,000
Net Book Value							0
Asset Retirement Obligation							837,000,000
Proceeds from sale of business							1,000
Percentage of Undivided Ownership Interest										100.00%
Reduction to income tax expense							$ 156,000,000
Entergy Wholesale Commodities [Member]
Business Acquisition [Line Items]
Reduction to income tax expense												174,000,000
Entergy Texas [Member]
Business Acquisition [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax																$ 1,902,511,000	1,587,125,000	1,488,955,000
Proceeds from Sale of Productive Assets																67,920,000	0	0
Net Book Value		7,181,567,000														7,181,567,000	6,007,687,000
Asset Retirement Obligation		8,500,000										$ 7,600,000				8,500,000	8,100,000	7,600,000
Assets, Fair Value Disclosure		27,400,000														27,400,000	286,400,000
Equity Method Investments		$ 300,000														$ 300,000	349,000
Acquisitions And Dispositions																ACQUISITIONS, DISPOSITIONS, AND IMPAIRMENT OF LONG-LIVED ASSETS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas) Acquisitions Searcy Solar Facility In March 2019, Entergy Arkansas entered into a build-own-transfer agreement for the purchase of an approximately 100 MW solar energy facility to be sited on approximately 800 acres in White County near Searcy, Arkansas. The project, Searcy Solar facility, was being constructed by a subsidiary of NextEra Energy Resources. In April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership to acquire and own the facility. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. The APSC approved Entergy Arkansas’s tax equity partnership request in September 2021. AR Searcy Partnership, LLC was formed for the tax equity partnership with Entergy Arkansas as its managing member. In November 2021 both Entergy Arkansas and the tax equity investor made capital contributions to the tax equity partnership that were then used to acquire the facility. Upon substantial completion of the facility in December 2021, the tax equity partnership completed the purchase of the Searcy Solar facility. The purchase price for the Searcy Solar facility was approximately $133 million, which includes a final payment of approximately $1 million to be made in 2022. See Note 1 to the financial statements for further discussion of the HLBV method of accounting used to account for the investment in AR Searcy Partnership, LLC. Hardin County Peaking Facility In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $68 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $37 million. Washington Parish Energy Center In April 2017, Entergy Louisiana entered into an agreement with a subsidiary of Calpine Corporation for the construction and purchase of Washington Parish Energy Center, which consists of two natural gas-fired combustion turbine units with a total nominal capacity of approximately 361 MW. In November 2020, Entergy Louisiana completed the purchase, as approved by the LPSC, of the Washington Parish Energy Center. The total investment including transmission and other related costs, is approximately $261 million, including a payment of $222 million to purchase the plant. Choctaw Generating Station In October 2019, Entergy Mississippi purchased the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi, from a subsidiary of GenOn Energy Inc. The purchase price for the Choctaw Generating Station was approximately $305 million. Dispositions Indian Point Energy Center In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and the asset retirement obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $190 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets. Vermont Yankee In November 2016, Entergy entered into an agreement to sell 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee was the owner of the Vermont Yankee plant. The sale of Entergy Nuclear Vermont Yankee to NorthStar included the transfer of the nuclear decommissioning trust fund and the asset retirement obligation for the spent fuel management and decommissioning of the plant. In March 2018, Entergy and NorthStar entered into a settlement agreement and a Memorandum of Understanding with State of Vermont agencies and other interested parties that set forth the terms on which the agencies and parties support the Vermont Public Utility Commission’s approval of the transaction. The agreements provide additional financial assurance for decommissioning, spent fuel management and site restoration, and detail the site restoration standards. In October 2018 the NRC issued an order approving the application to transfer Vermont Yankee’s license to NorthStar for decommissioning. In December 2018 the Vermont Public Utility Commission issued an order approving the transaction consistent with the Memorandum of Understanding’s terms. On January 11, 2019, Entergy and NorthStar closed the transaction. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. A subsidiary of Entergy assumed the obligations under the credit facility, which remains outstanding. At the closing of the sale transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to the Entergy subsidiary that assumed the credit facility obligations. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. With the receipt of the NRC and Vermont Public Utility Commission approvals and the resolution among the parties of the significant conditions of the sale, Entergy concluded that as of December 31, 2018, Vermont Yankee was in held for sale status. Entergy accordingly evaluated the Vermont Yankee asset retirement obligation in light of the terms of the sale transaction and evaluated the remaining values of the Vermont Yankee assets. These evaluations resulted in an increase in the asset retirement obligation and $173 million of asset impairment and related other charges in the fourth quarter 2018. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019. The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Impairment of Long-lived Assets 2019, 2020, and 2021 Impairments Entergy continues to execute its strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet, with a planned shutdown of the only remaining operating plant, Palisades, by May 31, 2022. The other five Entergy Wholesale Commodities’ nuclear plants, FitzPatrick, Vermont Yankee, Pilgrim, Indian Point 2, and Indian Point 3, have been sold. The FitzPatrick plant was classified as held-for-sale at December 31, 2016, and subsequently sold to Exelon in March 2017. The Vermont Yankee plant was classified as held-for-sale at December 31, 2018, and subsequently sold to NorthStar on January 11, 2019. The Pilgrim plant was sold to Holtec International on August 26, 2019. The Indian Point 2 and Indian Point 3 plants were sold to Holtec International on May 28, 2021. Entergy Wholesale Commodities incurred $7 million in 2021, $19 million in 2020, and $100 million in 2019 of impairment charges primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business. With respect to Palisades, Entergy and Consumers Energy had agreed to amend the existing PPA so that it would terminate early, on May 31, 2018. In September 2017, however, Entergy and Consumers Energy agreed to terminate the PPA amendment agreement. Entergy continues to operate Palisades under the current PPA with Consumers Energy, instead of shutting down in the fall of 2018 as previously planned. Entergy intends to shut down the Palisades plant permanently no later than May 31, 2022. As a result of the change in expected operating life of the Palisades plant, the expected probability-weighted undiscounted net cash flows as of September 30, 2017 exceeded the carrying value of the plant and related assets. Accordingly, nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets incurred at Palisades after September 30, 2017 are no longer charged to expense as incurred, but recorded as assets and depreciated or amortized, subject to the typical periodic impairment reviews prescribed in the accounting rules. The impairments and other related charges are recorded as a separate line item in Entergy’s consolidated statements of operations and are included within the results of the Entergy Wholesale Commodities segment. In addition to the impairments and other related charges, Entergy expects to incur additional charges through mid-2022 associated with these strategic transactions. See Note 13 to the financial statements for further discussion of these additional charges.
Entergy Wholesale Commodities [Member]
Business Acquisition [Line Items]
Payments to Acquire Productive Assets																$ 12,100,000	54,455,000	104,300,000
Asset Write-Offs, Impairments, And Related Charges																264,000,000	19,000,000	290,000,000
Asset impairment primarily related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets																$ 7,000,000	19,000,000	100,000,000
Entergy Wholesale Commodities [Member] | Vermont Yankee [Member]
Business Acquisition [Line Items]
Percent of Equity Interest to be included in nuclear plant purchase and sale agreement											100.00%
Palisades [Member] | Entergy Wholesale Commodities [Member]
Business Acquisition [Line Items]
Average Price Under PPA | $ / MWh																51
Amortization of Intangible Assets																$ 12,000,000	$ 11,000,000	$ 10,000,000
Palisades [Member] | Entergy Wholesale Commodities [Member] | Subsequent Event [Member]
Business Acquisition [Line Items]
Accelerated Finite Lived Intangible Assets Amortization Expenses due to termination of PPA															$ 5,000,000
Vermont Yankee [Member] | Entergy Louisiana [Member]
Business Acquisition [Line Items]
Capacity Of Power Plant Unit | MW					361
Payments to Acquire Productive Assets					$ 261,000,000
Payments to Acquire Property, Plant, and Equipment					$ 222,000,000
Choctaw [Member] | Entergy Mississippi [Member]
Business Acquisition [Line Items]
Capacity Of Power Plant Unit | MW						810
Payments to Acquire Productive Assets						$ 305,000,000
Vermont Yankee [Member]
Business Acquisition [Line Items]
After-Tax Asset Impairment Charge													4,200,000
Discontinued Operation, Tax Effect of Discontinued Operation													29,000,000
Restructuring Costs and Asset Impairment Charges													$ 5,400,000
Vermont Yankee [Member] | Entergy Wholesale Commodities [Member]
Business Acquisition [Line Items]
Increase (Decrease) in Notes Payable, Current									$ 139,000,000
Asset Impairment Charges														$ 173,000,000
Montgomery County Power Station | Entergy Texas [Member]
Business Acquisition [Line Items]
Proceeds from Sale of Productive Assets			$ 68,000,000
Percentage of Undivided Ownership Interest			7.56%
Searcy Solar Facility | Entergy Arkansas [Member]
Business Acquisition [Line Items]
Capacity Of Power Plant Unit | MW		100
Searcy Solar Facility | Entergy Arkansas [Member] | AR Searcy Partnership, LLC
Business Acquisition [Line Items]
Payments to Acquire Productive Assets		$ 133,000,000
Searcy Solar Facility | Entergy Arkansas [Member] | Subsequent Event [Member] | AR Searcy Partnership, LLC
Business Acquisition [Line Items]
Payments to Acquire Productive Assets	$ 1,000,000
Indian Point Energy Center | Entergy Wholesale Commodities [Member]
Business Acquisition [Line Items]
Decommissioning Trust Fair Values																			$ 2,387,000,000
Asset Retirement Obligation																			$ 1,996,000,000
Percentage of Undivided Ownership Interest								100.00%
Gain (Loss) on Disposition of Assets				$ 340,000,000
Gain (Loss) on Disposition of Assets (Net-Of-Tax)				$ 268,000,000
Hardin County Peaking Facility | Entergy Texas [Member]
Business Acquisition [Line Items]
Capacity Of Power Plant Unit | MW			147
Payments to Acquire Productive Assets			$ 37,000,000

Risk Management and Fair Valu_3

Risk Management and Fair Values Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022TWh	Dec. 31, 2021USD ($)GWhMMBTU	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Risk Management and Fair Values [Abstract]
Included in earnings			$ (0.3)	$ (9.2)
Maturity of cash flow hedges, Tax		$ 8	31	$ 20
Debt Securities, Available-for-sale, Allowance for Credit Loss		0.4	0.1
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted		$ 8	5
Letters of Credit Held			39
Utility [Member]
Risk Management and Fair Values [Abstract]
Letters Of Credit			1
Power Contracts [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted			5
Letters of Credit Held			39
Gas Hedge Contracts [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		33,083,500
Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Total volume of FTRs outstanding (MWh) | GWh		57,836
Subsequent Event [Member] | Power Contracts [Member]
Risk Management and Fair Values [Abstract]
Planned generation sold forward from non utility nuclear power plants	99.00%
Total planned generation for remainder of the period | TWh	2.8
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Total volume of FTRs outstanding (MWh) | GWh		12,561
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		16,420,000
Maximum Length of Time Hedged in Cash Flow Hedge		2 years 3 months
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount			0.3
Total volume of FTRs outstanding (MWh) | GWh		25,973
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		16,017,800
Maximum Length of Time Hedged in Cash Flow Hedge		10 months
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 0.2	0.2
Total volume of FTRs outstanding (MWh) | GWh		6,429
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		645,700
Maximum Length of Time Hedged in Cash Flow Hedge		3 months
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount			0.2
Total volume of FTRs outstanding (MWh) | GWh		2,643
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 0.1	$ 0.5
Total volume of FTRs outstanding (MWh) | GWh		10,003

Risk Management and Fair Valu_4

Risk Management and Fair Values Fair Values Of Derivative Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Entergy Wholesale Commodities [Member]
Liabilities:
Cash collateral posted	$ 8	$ 5
Prepayments And Other [Member] | Electricity Futures Forwards Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated as Hedging Instrument [Member]
Assets:
Derivative asset, fair value		39
Derivative asset as hedging instrument offset		(1)
Derivative Asset		38
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	6	1
Derivative asset as hedging instrument offset		0
Derivative Asset	6	1
Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	4	9
Derivative asset as hedging instrument offset		0
Derivative Asset	4	9
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	5	1
Derivative asset as hedging instrument offset		0
Derivative Asset	5	1
Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1
Derivative Liability		1
Derivative Liability, Fair Value, Gross Liability		1
Other Current Liabilities [Member] | Electricity Futures Forwards Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated as Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1
Derivative liability as hedging instrument offset		(1)
Derivative Liability		0
Derivative Liability, Fair Value, Gross Liability		1
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	7	6
Derivative liability as hedging instrument offset	0
Derivative Liability	7	6
Derivative Liability, Fair Value, Gross Liability	7	6
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	5.7	0.8
Derivative asset as hedging instrument offset	0	0
Derivative Asset	5.7	0.8
Entergy Louisiana [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	0.6	4.3
Derivative asset as hedging instrument offset	0	0.1
Derivative Asset	0.6	4.2
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	5.3	0.5
Derivative asset as hedging instrument offset	0	0
Derivative Asset	5.3	0.5
Entergy Louisiana [Member] | Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1.3
Derivative liability as hedging instrument offset		0
Derivative Liability		1.3
Derivative Liability, Fair Value, Gross Liability		1.3
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		0.3
Derivative liability as hedging instrument offset		0
Derivative Liability		0.3
Derivative Liability, Fair Value, Gross Liability		0.3
Entergy Arkansas [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	2.3	2.9
Derivative asset as hedging instrument offset	0	0.2
Derivative Asset	2.3	2.7
Entergy Mississippi [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	0.3	0.6
Derivative asset as hedging instrument offset	0	0
Derivative Asset	0.3	0.6
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	6.7	5
Derivative liability as hedging instrument offset	0	0
Derivative Liability	6.7	5
Derivative Liability, Fair Value, Gross Liability	6.7	5
Entergy New Orleans [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	0.1	0.2
Derivative asset as hedging instrument offset	0	0.1
Derivative Asset	0.1	0.1
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	0.5	0.3
Derivative liability as hedging instrument offset	0	0
Derivative Liability	0.5	0.3
Derivative Liability, Fair Value, Gross Liability	0.5	0.3
Entergy Texas [Member] | Prepayments And Other [Member] | Financial Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative asset, fair value	0.8	1.6
Derivative asset as hedging instrument offset	0	0
Derivative Asset	$ 0.8	$ 1.6

Risk Management and Fair Valu_5

Risk Management and Fair Values Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Futures Forwards Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 2	$ 77	$ 232
Maturity of cash flow hedges, before taxes	$ 40	$ 148	$ 97

Risk Management and Fair Valu_6

Risk Management and Fair Values Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income (Details) - Not Designated As Hedging Instrument [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	$ 32	$ (12)	$ (13)
Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	179	92	94
Competitive Businesses Operating Revenues [Member] | Electricity Futures Forwards Swaps And Options [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	(2)	1	12
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	12.6		(5.3)
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	31.6	19.6	46.7
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	19.8	(11.1)	(7.7)
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	11.3	3	6.8
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	(0.1)	(0.8)
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	4.3	1.4	2.7
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	42.6	26.7	22.3
Entergy Texas [Member] | Purchased Power Expense [Member] | Financial Transmission Rights (FTRs) [Member]
Effect of Derivative instruments not designated as hedging instruments on the consolidated statements of income
Amount of gain (loss) recorded in income	$ 85.9	$ 40.4	$ 15.7

Risk Management and Fair Valu_7

Risk Management and Fair Values Assets And Liabilities At Fair Value On A Recurring Basis (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 397,615,000	$ 1,630,248,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow	49,000,000	148,000,000
Restricted Cash and Cash Equivalents, Current	29,000,000	42,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	6,005,000,000	9,122,000,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	7,000,000	7,000,000
Equity Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	132,000,000	1,533,000,000
Common trust funds valued using Net Asset Value [Domain]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	3,205,000,000	3,103,000,000
Power Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset		38,000,000
Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	4,000,000	9,000,000
Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	11,000,000	2,000,000
Debt Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	2,177,000,000	2,617,000,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	398,000,000	1,630,000,000
Equity Securities, FV-NI	132,000,000	1,533,000,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow	49,000,000	148,000,000
Restricted Cash and Cash Equivalents, Current	29,000,000	42,000,000
Liabilities at fair value on a recurring basis
Debt Securities	770,000,000	919,000,000
Assets, Fair Value Disclosure	1,384,000,000	4,273,000,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	7,000,000	6,000,000
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset		0
Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	6,000,000	1,000,000
Fair Value Inputs Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Debt Securities	1,407,000,000	1,698,000,000
Assets, Fair Value Disclosure	1,412,000,000	1,699,000,000
Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	1,000,000
Fair Value Inputs Level 2 [Member] | Power Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset		0
Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	5,000,000	1,000,000
Fair Value Inputs Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Debt Securities	0	0
Assets, Fair Value Disclosure	4,000,000	47,000,000
Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	0
Fair Value Inputs Level 3 [Member] | Power Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset		38,000,000
Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	4,000,000	9,000,000
Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy New Orleans [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	42,836,000	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		83,000,000
Restricted Cash and Cash Equivalents, Current	2,000,000	3,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	44,900,000	86,500,000
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	500,000	300,000
Entergy New Orleans [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	100,000	100,000
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	42,800,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		83,000,000
Restricted Cash and Cash Equivalents, Current	2,000,000	3,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	44,800,000	86,400,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	500,000	300,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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 at fair value on a recurring basis
Replacement Reserve Escrow		0
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy New Orleans [Member] | Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	0
Entergy New Orleans [Member] | Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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 at fair value on a recurring basis
Replacement Reserve Escrow		0
Restricted Cash and Cash Equivalents, Current	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	100,000	100,000
Entergy New Orleans [Member] | Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	0
Entergy New Orleans [Member] | Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	100,000	100,000
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	47,598,000	7,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900,000	64,600,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	96,800,000	65,200,000
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	6,700,000	5,000,000
Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	300,000	600,000
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	47,600,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900,000	64,600,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	96,500,000	64,600,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	6,700,000	5,000,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy Mississippi [Member] | Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	0
Entergy Mississippi [Member] | Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	300,000	600,000
Entergy Mississippi [Member] | Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability	0	0
Entergy Mississippi [Member] | Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	300,000	600,000
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	18,378,000	726,717,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		2,700,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	2,144,500,000	2,528,900,000
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability		1,600,000
Entergy Louisiana [Member] | Equity Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	20,200,000	8,700,000
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	1,300,100,000	1,153,100,000
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	600,000	4,200,000
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	11,000,000	1,300,000
Entergy Louisiana [Member] | Debt Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	794,200,000	632,200,000
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	18,400,000	726,700,000
Equity Securities, FV-NI	20,200,000	8,700,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		2,700,000
Liabilities at fair value on a recurring basis
Debt Securities	262,600,000	172,400,000
Assets, Fair Value Disclosure	306,900,000	911,300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability		300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	5,700,000	800,000
Entergy Louisiana [Member] | Fair Value Inputs Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0
Liabilities at fair value on a recurring basis
Debt Securities	531,600,000	459,800,000
Assets, Fair Value Disclosure	536,900,000	460,300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability		1,300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy Louisiana [Member] | Fair Value Inputs Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	5,300,000	500,000
Entergy Louisiana [Member] | Fair Value Inputs Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0
Liabilities at fair value on a recurring basis
Debt Securities	0	0
Assets, Fair Value Disclosure	600,000	4,200,000
Entergy Louisiana [Member] | Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Derivative Liability		0
Entergy Louisiana [Member] | Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	600,000	4,200,000
Entergy Louisiana [Member] | Fair Value Inputs Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Temporary Cash Investments Fair Value		248,600,000
Cash Equivalents, at Carrying Value	0	248,570,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	27,400,000	286,400,000
Entergy Texas [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	26,600,000	36,200,000
Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	800,000	1,600,000
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Temporary Cash Investments Fair Value		248,600,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	26,600,000	284,800,000
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	26,600,000	36,200,000
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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]
Temporary Cash Investments Fair Value		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0	0
Entergy Texas [Member] | Fair Value Inputs Level 2 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Entergy Texas [Member] | Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
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]
Temporary Cash Investments Fair Value		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	800,000	1,600,000
Entergy Texas [Member] | Fair Value Inputs Level 3 [Member] | Securitization Recovery Trust Account [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0	0
Entergy Texas [Member] | Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	800,000	1,600,000
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	4,760,000	168,020,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,445,500,000	1,444,600,000
Entergy Arkansas [Member] | Equity Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	16,700,000	1,300,000
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	895,400,000	824,700,000
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	2,300,000	2,700,000
Entergy Arkansas [Member] | Debt Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	526,300,000	447,900,000
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	4,800,000	168,000,000
Equity Securities, FV-NI	16,700,000	1,300,000
Liabilities at fair value on a recurring basis
Debt Securities	119,500,000	98,200,000
Assets, Fair Value Disclosure	141,000,000	267,500,000
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy Arkansas [Member] | Fair Value Inputs Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Liabilities at fair value on a recurring basis
Debt Securities	406,800,000	349,700,000
Assets, Fair Value Disclosure	406,800,000	349,700,000
Entergy Arkansas [Member] | Fair Value Inputs Level 2 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	0	0
Entergy Arkansas [Member] | Fair Value Inputs Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0	0
Equity Securities, FV-NI	0	0
Liabilities at fair value on a recurring basis
Debt Securities	0	0
Assets, Fair Value Disclosure	2,300,000	2,700,000
Entergy Arkansas [Member] | Fair Value Inputs Level 3 [Member] | Financial Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Derivative Asset	2,300,000	2,700,000
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	89,114,000	216,383,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,474,400,000	1,432,300,000
System Energy [Member] | Equity Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	12,900,000	3,800,000
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	847,900,000	784,400,000
System Energy [Member] | Debt Securities [Member]
Liabilities at fair value on a recurring basis
Decommissioning Trust Fair Values	524,500,000	427,700,000
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	89,100,000	216,400,000
Equity Securities, FV-NI	12,900,000	3,800,000
Liabilities at fair value on a recurring basis
Debt Securities	273,000,000	177,300,000
Assets, Fair Value Disclosure	375,000,000	397,500,000
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	0
Equity Securities, FV-NI	0	0
Liabilities at fair value on a recurring basis
Debt Securities	251,500,000	250,400,000
Assets, Fair Value Disclosure	251,500,000	250,400,000
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	0
Equity Securities, FV-NI	0	0
Liabilities at fair value on a recurring basis
Debt Securities	0	0
Assets, Fair Value Disclosure	$ 0	$ 0

Risk Management and Fair Valu_8

Risk Management and Fair Values Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Included in earnings		$ (0.3)	$ (9.2)
Issuances of financial transmission rights	$ 0	0	0
Financial Transmission Rights (FTRs) [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	162	67	54
Issuances of financial transmission rights	12	23	35
Gains (losses) included as a regulatory liability/asset	0	1	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(179)	(92)	(94)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	4	9	10	$ 15
Electricity Futures Forwards Swaps And Options [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	2	77	232
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0	0	0
Gains (losses) included as a regulatory liability/asset		1	12
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	(2)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(38)	(158)	(95)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0	38	118
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value				$ (31)
Entergy Arkansas [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	39.4	19.6
Issuances of financial transmission rights	2.8	6.5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(42.6)	(26.7)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	2.3	2.7	3.3
Entergy Louisiana [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	23.9	6.1
Issuances of financial transmission rights	4.1	13.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(31.6)	(19.6)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.6	4.2	4.5
Entergy Mississippi [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	9.3	1.4
Issuances of financial transmission rights	1.7	1.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(11.3)	(3)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.3	0.6	0.8
Entergy New Orleans [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	3.9	1.3
Issuances of financial transmission rights	0.4	(0.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(4.3)	(1.4)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.1	0.1	0.3
Entergy Texas [Member]
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	82.4	38.7
Issuances of financial transmission rights	2.7	2.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(85.9)	(40.4)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 0.8	$ 1.6	$ 0.9

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 31, 2021
Decommissioning Fund Investments	$ 5,514,016	$ 7,253,215
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	(28,435)	17,586	$ 14,023
Amortized cost of debt securities	$ 2,125,000	2,423,000
Average coupon rate of debt securities	2.74%
Proceeds from the dispositions of debt securities	$ 1,465,000	1,024,000	1,427,000
Average Duration of Debt Securities in Years	6 years 11 months 8 days
Average Maturity of Debt Securities, Years	10 years 6 months 18 days
Equity Securities, FV-NI, Unrealized Gain	$ 605,000
Debt Securities, Available-for-sale, Allowance for Credit Loss	400	100
Debt Securities, Available-for-sale, Realized Gain	29,000	47,000	25,000
Debt Securities, Available-for-sale, Realized Loss	17,000	4,000	4,000
Entergy Arkansas [Member]
Decommissioning Fund Investments	1,438,416	1,273,921
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 519,600	420,400
Average coupon rate of debt securities	2.28%
Proceeds from the dispositions of debt securities	$ 57,600	94,500	110,600
Average Duration of Debt Securities in Years	6 years 5 months 8 days
Average Maturity of Debt Securities, Years	7 years 6 months 29 days
Equity Securities, FV-NI, Unrealized Gain	$ 163,200
Debt Securities, Available-for-sale, Realized Gain	2,500	8,800	2,900
Debt Securities, Available-for-sale, Realized Loss	600	200	100
Entergy Louisiana [Member]
Decommissioning Fund Investments	$ 2,114,523	1,794,042
Percentage Interest in River Bend	30.00%
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 766,300	581,400
Average coupon rate of debt securities	3.30%
Proceeds from the dispositions of debt securities	$ 303,400	159,700	186,000
Average Duration of Debt Securities in Years	6 years 9 months 29 days
Average Maturity of Debt Securities, Years	12 years 3 months 14 days
Equity Securities, FV-NI, Unrealized Gain	$ 249,400
Debt Securities, Available-for-sale, Realized Gain	6,800	8,100	4,800
Debt Securities, Available-for-sale, Realized Loss	4,100	700	300
System Energy [Member]
Decommissioning Fund Investments	1,385,254	1,215,868
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 515,600	398,400
Average coupon rate of debt securities	2.33%
Proceeds from the dispositions of debt securities	$ 513,800	252,200	338,100
Average Duration of Debt Securities in Years	7 years 3 months 29 days
Average Maturity of Debt Securities, Years	10 years 1 month 24 days
Equity Securities, FV-NI, Unrealized Gain	$ 155,100
Debt Securities, Available-for-sale, Realized Gain	9,300	11,500	5,400
Debt Securities, Available-for-sale, Realized Loss	4,000	600	$ 700
Indian Point 3 [Member]
Decommissioning Trust Fair Values		991,000
Indian Point 1 [Member]
Decommissioning Trust Fair Values		631,000
Indian Point 2 [Member]
Decommissioning Trust Fair Values		794,000
Palisades [Member]
Decommissioning Trust Fair Values	576,000	554,000
Indian Point [Member]
Decommissioning Trust Fair Values				$ 2,387,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	$ 2,000	$ 31,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Total	$ 2,177	$ 2,617
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Total	2,177	2,617
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	65	197
Debt Securities, Available-for-sale, Unrealized Loss Position	12	3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Total	794.2	632.2
Entergy Louisiana [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Total	794.2	632.2
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	31.3	51.3
Debt Securities, Available-for-sale, Unrealized Loss Position	3.3	0.5
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Total	526.3	447.9
Entergy Arkansas [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Total	526.3	447.9
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	11.4	27.7
Debt Securities, Available-for-sale, Unrealized Loss Position	4.7	0.3
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Total	524.5	427.7
System Energy [Member] | Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Total	524.5	427.7
Debt Securities, Available-for-sale, Accumulated Gross Unrealized Gain, before Tax	11.8	30
Debt Securities, Available-for-sale, Unrealized Loss Position	$ 2.9	$ 0.8

Decommissioning Trust Funds (Av

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	$ 12	$ 3
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	770	187
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	99	2
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	869	189
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	8	3
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	4	0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	4.7	0.3
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	183.8	29.9
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	39.5	0
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	223.3	29.9
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	2.9	0.3
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	1.8	0
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	3.3	0.5
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	206.9	36.4
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	42.9	0.8
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	249.8	37.2
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	1.4	0.5
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	1.9	0
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Debt Securities, Available-for-sale, Unrealized Loss Position	2.9	0.8
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value	276.6	28.9
Debt Securities, Held-to-maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value	11.3	0
Debt Securities, Held-to-maturity, Unrealized Loss Position, Fair Value	287.9	28.9
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, Less than 12 Months	2.3	0.8
Debt Securities, Available-for-sale, Continuous Unrealized Loss Position, 12 Months or Longer	$ 0.6	$ 0

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair value of debt securities by contractual maturities
1 year - 5 years	$ 473	$ 672
5 years - 10 years	655	852
10 years - 15 years	389	377
15 years - 20 years	130	144
20 years+	530	576
Total	2,177	2,617
Debt Securities Available For Sale Maturity Allocated And Single Maturity Date Within One Year Negative Fair Value	0	(4)
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	0	0
1 year - 5 years	91.7	113.1
5 years - 10 years	217.4	189.8
10 years - 15 years	146	81.4
15 years - 20 years	35.7	28.5
20 years+	35.5	35.1
Total	526.3	447.9
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	0	0
1 year - 5 years	157.8	117
5 years - 10 years	173	159.4
10 years - 15 years	123	101.2
15 years - 20 years	80.2	66.9
20 years+	260.2	187.7
Total	794.2	632.2
System Energy [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	156.8	134.7
5 years - 10 years	161.8	141.5
10 years - 15 years	58.6	31.5
15 years - 20 years	1.9	5.3
20 years+	145.4	115.8
Total	524.5	427.7
Debt Securities Available For Sale Maturity Allocated And Single Maturity Date Within One Year Negative Fair Value	$ 0	$ (1.1)

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Variable Interest Entities (Textual) [Abstract]
Assets	$ 59,454,242	$ 58,239,212
System Energy [Member]
Variable Interest Entities (Textual) [Abstract]
Assets	4,372,624	4,413,968
System Energy [Member] | Grand Gulf [Member]
Variable Interest Entities (Textual) [Abstract]
Payments on lease, including interest	17,200	17,200	$ 17,200
Entergy Arkansas [Member]
Variable Interest Entities (Textual) [Abstract]
Assets	12,565,119	$ 12,100,131
Entergy Arkansas [Member] | AR Searcy Partnership, LLC
Variable Interest Entities (Textual) [Abstract]
Assets	140,000
Ownership Interest in Partnership, Carrying Value	$ 107,000

Transactions With Affiliates (D

Transactions With Affiliates (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Entergy Arkansas [Member]
Intercompany revenues	$ 109.8	$ 105.2	$ 117.5
Intercompany operating expenses	559.7	515.5	534
Intercompany interest and investment income	0	0	0.4
Entergy Louisiana [Member]
Intercompany revenues	289.9	280.5	277.8
Intercompany operating expenses	755.2	661.5	665.4
Intercompany interest and investment income	127.6	127.7	128.5
Entergy Mississippi [Member]
Intercompany revenues	1.4	1.2	1.4
Intercompany operating expenses	299.8	283.3	306.7
Intercompany interest and investment income	0	0.1	0.4
Entergy New Orleans [Member]
Intercompany revenues	0	0	0
Intercompany operating expenses	287.8	266	292.1
Intercompany interest and investment income	0	0	0
Entergy Texas [Member]
Intercompany revenues	64.3	40.4	51.6
Intercompany operating expenses	275	260.3	255
Intercompany interest and investment income	0	0	0.4
System Energy [Member]
Intercompany revenues	545.6	520.7	584.1
Intercompany operating expenses	190.8	177.4	156.2
Intercompany interest and investment income	0	0.2	1
EWO Marketing, LLC [Member] | RS Cogen [Member]
Intercompany operating expenses	$ 24	$ 26	$ 24.5

Transactions With Affiliates Tr

Transactions With Affiliates Transactions with Affiliates (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
EWO Marketing, LLC [Member] | RS Cogen [Member]
Related Party Transaction [Line Items]
Intercompany operating expenses	$ 24	$ 26	$ 24.5

Revenue Recognition Revenue R_3

Revenue Recognition Revenue Recognition (Narrative) (Details) $ in Millions	5 Months Ended	12 Months Ended				29 Months Ended	156 Months Ended
	May 31, 2022$ / MWh	Dec. 31, 2022USD ($)	Dec. 31, 2021USD ($)$ / MWh	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	May 31, 2022$ / MWh	Dec. 31, 2019$ / MWh
Regulatory asset related to incremental bad debt expense resulting from COVID-19			$ 30.4	$ 87.1
System Energy [Member]
Percent Interest in Grand Gulf			90.00%
Entergy Louisiana [Member]
Regulatory asset related to incremental bad debt expense resulting from COVID-19			$ 7.4	36
Entergy Mississippi [Member]
Regulatory asset related to incremental bad debt expense resulting from COVID-19			(2.4)	15.5
Entergy Texas [Member]
Regulatory asset related to incremental bad debt expense resulting from COVID-19			$ (1.1)	12.9
Entergy Wholesale Commodities [Member] | Palisades [Member]
Average Price Under PPA | $ / MWh			51
Amortization of Intangible Assets			$ 12	$ 11	$ 10
Contract price under purchase power agreement | $ / MWh							43.50
Entergy Wholesale Commodities [Member] | Scenario, Forecast [Member] | Palisades [Member]
Contract price under purchase power agreement | $ / MWh						24.14
Subsequent Event [Member] | Entergy Wholesale Commodities [Member] | Palisades [Member]
Accelerated Finite Lived Intangible Assets Amortization Expenses due to termination of PPA		$ 5
Contract price under purchase power agreement | $ / MWh	61.50

Revenue Recognition Revenue R_4

Revenue Recognition Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer, Excluding Assessed Tax	$ 11,742,896	$ 10,113,636	$ 10,878,673
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	10,873,995	9,046,643	9,429,978
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	170,610	124,008	153,954
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	698,291	942,985	1,294,741
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,981,846	3,550,317	3,531,500
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,610,207	2,292,740	2,475,586
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,942,370	2,331,170	2,541,287
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	245,685	212,131	228,470
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	601,895	295,810	285,722
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	375,312	348,102	343,143
Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	10,757,315	9,030,270	9,405,708
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	116,680	16,373	24,270
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	25,798	171,625	130,189
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	672,493	771,360	1,164,552
Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,780,108	8,386,358	8,776,843
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,338,590	2,084,494	2,259,594
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,338,590	2,084,494	2,259,594
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	882,773	841,162	795,269
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	480,401	466,273	538,850
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	496,661	461,907	520,958
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	19,112	18,011	20,795
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	311,791	173,115	257,864
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	130,443	109,642	112,618
Entergy Arkansas [Member] | Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,321,181	2,070,110	2,246,354
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,409	14,384	13,240
Entergy Arkansas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,878,947	1,787,353	1,875,872
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,068,448	4,069,862	4,285,175
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,994,459	4,019,063	4,223,027
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	73,989	50,799	62,148
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,484,612	1,270,187	1,270,478
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,055,825	886,548	947,412
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,771,311	1,314,234	1,450,966
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	82,503	68,901	71,046
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	391,424	333,594	333,395
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	148,304	141,004	135,783
Entergy Louisiana [Member] | Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,933,979	4,014,468	4,209,080
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	60,480	4,595	13,947
Entergy Louisiana [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,394,251	3,539,870	3,739,902
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,406,346	1,247,854	1,323,043
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,406,346	1,247,854	1,323,043
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	578,258	523,379	562,219
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	439,950	395,875	444,173
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	150,698	145,100	164,491
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	46,248	41,955	44,300
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	124,632	77,530	39,295
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,357	54,590	58,269
Entergy Mississippi [Member] | Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,398,143	1,238,429	1,312,747
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8,203	9,425	10,296
Entergy Mississippi [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,215,154	1,106,309	1,215,183
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	768,852	633,841	686,223
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	672,231	560,632	594,417
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	96,621	73,209	91,806
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	269,891	243,502	245,081
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	208,104	179,406	202,138
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	30,751	24,248	31,824
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	71,584	59,819	70,865
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	88,349	33,213	38,626
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,813	8,294	9,842
Entergy New Orleans [Member] | Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	670,492	548,482	598,376
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,739	12,150	(3,959)
Entergy New Orleans [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	580,330	506,975	549,908
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,902,511	1,587,125	1,488,955
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,902,511	1,587,125	1,488,955
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0
Entergy Texas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	766,312	672,087	658,453
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	425,927	364,638	343,013
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	492,949	385,681	373,048
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	26,238	23,445	21,464
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	145,719	100,273	59,074
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	41,805	39,981	32,424
Entergy Texas [Member] | Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,898,950	1,586,105	1,487,476
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,561	1,020	1,479
Entergy Texas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,711,426	1,445,851	1,395,978
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 570,848	$ 495,458	$ 573,410

Revenue Recognition (Allowance

Revenue Recognition (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Allowance for Doubtful Other Receivables, Current	$ 68.6	$ 117.7	$ 7.4
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	56.2	109
Accounts Receivable, Allowance for Credit Loss, Writeoff	(118.2)	(8.6)
Accounts Receivable, Allowance for Credit Loss, Recovery	12.9	9.9
Regulatory asset related to incremental bad debt expense resulting from COVID-19	30.4	87.1
Entergy Arkansas [Member]
Allowance for Doubtful Other Receivables, Current	13.1	18.3	1.2
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	30.4	16.2
Accounts Receivable, Allowance for Credit Loss, Writeoff	(38.9)	(1.8)
Accounts Receivable, Allowance for Credit Loss, Recovery	3.3	2.7
Regulatory asset related to costs associated with COVID-19 pandemic	32.6
Regulatory asset related to incremental bad debt expense resulting from COVID-19	22.2	10.5
Entergy Louisiana [Member]
Allowance for Doubtful Other Receivables, Current	29.2	45.7	1.9
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	16.7	43.7
Accounts Receivable, Allowance for Credit Loss, Writeoff	(38.3)	(3.5)
Accounts Receivable, Allowance for Credit Loss, Recovery	5.1	3.6
Regulatory asset related to costs associated with COVID-19 pandemic	56.3
Regulatory asset related to incremental bad debt expense resulting from COVID-19	7.4	36
Entergy New Orleans [Member]
Allowance for Doubtful Other Receivables, Current	13.3	17.4	3.2
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	7.3	14.1
Accounts Receivable, Allowance for Credit Loss, Writeoff	(12.3)	(1)
Accounts Receivable, Allowance for Credit Loss, Recovery	0.9	1.1
Regulatory asset related to costs associated with COVID-19 pandemic	17.4
Regulatory asset related to incremental bad debt expense resulting from COVID-19	4.3	12.2
Entergy Mississippi [Member]
Allowance for Doubtful Other Receivables, Current	7.2	19.5	0.6
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	0.7	18.8
Accounts Receivable, Allowance for Credit Loss, Writeoff	(15.7)	(1.2)
Accounts Receivable, Allowance for Credit Loss, Recovery	2.7	1.3
Regulatory asset related to costs associated with COVID-19 pandemic	15
Regulatory asset related to incremental bad debt expense resulting from COVID-19	(2.4)	15.5
Entergy Texas [Member]
Allowance for Doubtful Other Receivables, Current	5.8	16.8	$ 0.5
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	1.1	16.2
Accounts Receivable, Allowance for Credit Loss, Writeoff	(13)	(1.1)
Accounts Receivable, Allowance for Credit Loss, Recovery	0.9	1.2
Regulatory asset related to costs associated with COVID-19 pandemic	11.7
Regulatory asset related to incremental bad debt expense resulting from COVID-19	$ (1.1)	$ 12.9

Schedule II - Valuation And Q_2

Schedule II - Valuation And Qualifying Accounts (Details) - Allowance for Doubtful Accounts Receivable [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 117,794	$ 7,404	$ 7,322
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	57,517	111,687	2,806
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	106,703	1,297	2,724
Balance at End of Period	68,608	117,794	7,404
Entergy Arkansas [Member]
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	18,334	1,169	1,264
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	30,433	17,307	1,000
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	35,695	142	1,095
Balance at End of Period	13,072	18,334	1,169
Entergy New Orleans [Member]
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	17,430	3,226	3,222
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	6,850	14,204	316
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	10,998	0	312
Balance at End of Period	13,282	17,430	3,226
Entergy Mississippi [Member]
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	19,527	636	563
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	850	19,081	406
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	13,168	190	333
Balance at End of Period	7,209	19,527	636
Entergy Louisiana [Member]
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	45,693	1,902	1,813
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	17,219	44,542	762
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	33,681	751	673
Balance at End of Period	29,231	45,693	1,902
Entergy Texas [Member]
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	16,810	471	461
Valuation Allowances And Reserves Charged To Cost And Expense And Other Accounts	2,166	16,554	321
SEC Schedule, 12-09, Valuation Allowances and Reserves, Deduction	13,162	215	311
Balance at End of Period	$ 5,814	$ 16,810	$ 471

Uncategorized Items - etr-20211

Label	Element	Value
Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 8,844,305,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	10,258,256,000
Common Stock [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,700,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,616,000
Retained Earnings [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	8,727,956,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	9,257,190,000
Subsidiaries Preferred Stock and Noncontrolling Interest [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	35,000,000
AOCI Attributable to Parent [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(446,920,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(563,979,000)
Additional Paid-in Capital [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	6,564,436,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,951,431,000
Treasury Stock [Member] | Revision of Prior Period, Adjustment [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,154,150,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,273,719,000)
Accounting Standards Update 2016-13 [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(419,000)
Accounting Standards Update 2016-13 [Member] | Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(419,000)
Accounting Standards Update 2016-13 [Member] | Subsidiaries Preferred Stock and Noncontrolling Interest [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Update 2016-13 [Member] | Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	6,806,000
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | Subsidiaries Preferred Stock and Noncontrolling Interest [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(6,806,000)
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest
Accounting Standards Updates Nos. 2017-12 and 2017-08 [Member] | Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest