Entergy Texas (ETI-P) 10-Q 6 Aug 21 2021 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2021	Jul. 30, 2021
Entity Registrant Name	ENTERGY CORPORATION
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	72-1229752
Entity File Number	1-11299
Entity Central Index Key	0000065984
Document Type	10-Q
Document Period End Date	Jun. 30, 2021
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Incorporation, State or Country Code	DE
Entity Address, State or Province	639 Loyola Avenue
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70113
Entity Common Stock, Shares Outstanding		200,954,557
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true
Document Transition Report	false
NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETR
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock, $0.01 Par Value
CHICAGO STOCK EXCHANGE, INC [Member]
Trading Symbol	ETR
Security Exchange Name	CHX
Title of 12(b) Security	Common Stock, $0.01 Par Value
Entergy Arkansas [Member]
Entity Registrant Name	ENTERGY ARKANSAS, LLC
City Area Code	501
Local Phone Number	377-4000
Entity Tax Identification Number	83-1918668
Entity File Number	1-10764
Entity Central Index Key	0000007323
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	425 West Capitol Avenue
Entity Address, City or Town	Little Rock
Entity Address, State or Province	AR
Entity Address, Postal Zip Code	72201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Louisiana [Member]
Entity Registrant Name	ENTERGY LOUISIANA, LLC
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	47-4469646
Entity File Number	1-32718
Entity Central Index Key	0001348952
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	4809 Jefferson Highway
Entity Address, City or Town	Jefferson
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70121
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Mississippi [Member]
Entity Registrant Name	ENTERGY MISSISSIPPI, LLC
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	83-1950019
Entity File Number	1-31508
Entity Central Index Key	0000066901
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	308 East Pearl Street
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy New Orleans [Member]
Entity Registrant Name	ENTERGY NEW ORLEANS, LLC
City Area Code	504
Local Phone Number	670-3700
Entity Tax Identification Number	82-2212934
Entity File Number	1-35747
Entity Central Index Key	0000071508
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	1600 Perdido Street
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	70112
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Texas [Member]
Entity Registrant Name	ENTERGY TEXAS, INC.
City Area Code	409
Local Phone Number	981-2000
Entity Tax Identification Number	61-1435798
Entity File Number	1-34360
Entity Central Index Key	0001427437
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	10055 Grogans Mill Road
Entity Address, City or Town	The Woodlands
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77380
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
System Energy [Member]
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	72-0752777
Entity File Number	1-09067
Entity Central Index Key	0000202584
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	AR
Entity Address, State or Province	1340 Echelon Parkway
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39213
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Mortgage Bonds, Five Point Five Percent Series, Due April Two Thousand Sixty Six [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENO
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.50% Series due April 2066
Mortgage Bonds 5.0 Series Due December Two Thousand Fifty Two [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENJ
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.0% Series due December 2052
Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member] | Entergy Mississippi [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EMP
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due October 2066
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAI
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELC
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
5.375% Series A Preferred Stock, Cumulative, No Par Value [Domain] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETI/PR
Security Exchange Name	NYSE
Title of 12(b) Security	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,822,070	$ 2,412,788	$ 5,666,907	$ 4,839,967
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	626,064	341,005	1,127,231	738,408
Nuclear refueling outage expenses	43,700	44,894	87,438	95,112
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	781,118	736,261	1,487,904	1,438,345
Asset Impairment Charges	342,092	6,775	345,365	11,870
Decommissioning	86,199	95,413	184,841	189,097
Taxes, Other	155,911	158,646	312,613	328,940
Other Depreciation and Amortization	421,545	403,769	836,064	803,478
Other regulatory charges (credits) - net	(55,138)	(25,247)	(22,859)	(32,925)
Costs and Expenses	2,653,862	1,973,477	4,990,702	4,000,900
OPERATING INCOME	168,208	439,311	676,205	839,067
OTHER INCOME
Allowance for equity funds used during construction	16,873	28,370	31,449	64,324
Investment Income, Net	71,329	284,823	214,645	67,969
Miscellaneous - net	(62,844)	(93,620)	(123,773)	(70,232)
TOTAL	25,358	219,573	122,321	62,061
INTEREST EXPENSE
Interest Expense, Debt	220,340	216,799	426,226	422,388
Allowance for borrowed funds used during construction	(6,964)	(12,143)	(12,976)	(27,587)
TOTAL	213,376	204,656	413,250	394,801
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	(19,810)	454,228	385,276	506,327
Income taxes	(18,416)	89,115	47,526	17,921
Consolidated net income	(1,394)	365,113	337,750	488,406
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 4,580	$ 4,580	$ 9,159	$ 9,159
Earnings (loss) per average common share:
Basic (in dollars per share)	$ (0.03)	$ 1.80	$ 1.64	$ 2.40
Diluted (in dollars per share)	$ (0.03)	$ 1.79	$ 1.63	$ 2.39
Basic average number of common shares outstanding (in shares)	200,775,395	200,178,010	200,651,162	199,984,013
Diluted average number of common shares outstanding (in shares)	200,775,395	200,886,749	201,352,830	200,891,134
Net Income (Loss) Available to Common Stockholders, Basic	$ (5,974)	$ 360,533	$ 328,591	$ 479,247
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,641,375	2,190,557	5,179,794	4,241,196
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	31,998	22,495	90,166	66,471
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	148,697	199,736	396,947	532,300
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	252,371	211,961	632,105	428,575
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	349,040	297,954	685,659	591,876
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	65,613	38,730	125,810	102,027
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	73,899	66,343	141,730	128,680
Taxes, Other	27,076	22,697	52,975	49,887
Other Depreciation and Amortization	56,158	52,296	111,194	103,451
Other regulatory charges (credits) - net	(21,630)	(6,496)	(13,501)	(10,377)
Costs and Expenses	265,008	230,249	550,691	482,990
OPERATING INCOME	84,032	67,705	134,968	108,886
OTHER INCOME
Allowance for equity funds used during construction	2,029	1,588	3,697	3,027
Investment Income, Net	7	135	49	255
Miscellaneous - net	(2,205)	(2,589)	(4,518)	(4,885)
TOTAL	(169)	(866)	(772)	(1,603)
INTEREST EXPENSE
Interest Expense, Debt	18,922	17,192	36,535	33,775
Allowance for borrowed funds used during construction	(852)	(634)	(1,529)	(1,185)
TOTAL	18,070	16,558	35,006	32,590
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	65,793	50,281	99,190	74,693
Income taxes	14,377	11,388	21,802	13,274
Consolidated net income	51,416	38,893	77,388	61,419
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	349,040	297,954	685,659	591,876
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Mississippi [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	63,892	56,679	132,483	109,322
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	550,274	491,767	1,133,660	973,679
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	74,556	52,692	200,737	140,103
Nuclear refueling outage expenses	13,535	13,552	26,182	29,799
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	173,098	164,770	328,006	316,627
Decommissioning	19,280	18,206	38,280	36,147
Taxes, Other	30,106	27,172	59,849	58,232
Other Depreciation and Amortization	90,276	84,538	178,555	168,059
Other regulatory charges (credits) - net	(22,170)	(19,283)	(59,637)	(39,284)
Costs and Expenses	440,129	383,818	903,641	797,895
OPERATING INCOME	110,145	107,949	230,019	175,784
OTHER INCOME
Allowance for equity funds used during construction	3,608	3,878	6,601	6,795
Investment Income, Net	(2,739)	8,246	25,148	16,184
Miscellaneous - net	(5,372)	(6,133)	(11,163)	(12,569)
TOTAL	(4,503)	5,991	20,586	10,410
INTEREST EXPENSE
Interest Expense, Debt	35,624	35,969	69,410	71,592
Allowance for borrowed funds used during construction	(1,572)	(1,703)	(2,862)	(2,984)
TOTAL	34,052	34,266	66,548	68,608
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	71,590	79,674	184,057	117,586
Income taxes	14,997	19,504	34,427	12,821
Consolidated net income	56,593	60,170	149,630	104,765
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	550,274	491,767	1,133,660	973,679
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Arkansas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	61,448	42,171	131,669	88,212
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,267,598	1,011,652	2,375,242	1,942,299
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	355,362	161,610	500,596	306,102
Nuclear refueling outage expenses	12,193	13,654	25,475	27,284
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	275,599	226,216	513,082	448,874
Decommissioning	17,035	16,203	33,858	32,204
Taxes, Other	51,968	48,718	104,452	98,795
Other Depreciation and Amortization	163,061	154,255	323,874	299,390
Other regulatory charges (credits) - net	(21,617)	(19,202)	9,480	(8,070)
Costs and Expenses	1,040,197	755,240	1,907,374	1,519,108
OPERATING INCOME	227,401	256,412	467,868	423,191
OTHER INCOME
Allowance for equity funds used during construction	6,835	6,055	12,936	20,942
Investment Income, Net	59,457	93,807	131,972	74,138
Miscellaneous - net	(36,033)	(66,811)	(70,671)	(17,210)
TOTAL	30,259	33,051	74,237	77,870
INTEREST EXPENSE
Interest Expense, Debt	90,630	86,296	173,436	165,813
Allowance for borrowed funds used during construction	(3,068)	(3,202)	(5,827)	(10,334)
TOTAL	87,562	83,094	167,609	155,479
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	170,098	206,369	374,496	345,582
Income taxes	26,171	35,910	63,943	(14,273)
Consolidated net income	143,927	170,459	310,553	359,855
Earnings (loss) per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	143,927	170,459	310,553	359,855
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,254,579	1,001,601	2,334,242	1,914,142
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	13,019	10,051	41,000	28,157
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	186,596	153,786	396,557	314,529
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	178,740	147,343	348,075	296,645
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	34,510	16,836	53,522	44,331
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	40,977	29,126	79,155	59,830
Taxes, Other	12,294	15,642	24,850	28,848
Other Depreciation and Amortization	18,153	15,626	36,314	30,701
Other regulatory charges (credits) - net	2,575	4,526	5,705	(1,210)
Costs and Expenses	165,686	139,741	325,393	276,952
OPERATING INCOME	13,054	7,602	22,682	19,693
OTHER INCOME
Allowance for equity funds used during construction	376	2,048	634	4,533
Investment Income, Net	5	43	14	96
Miscellaneous - net	(204)	168	(506)	(570)
TOTAL	177	2,259	142	4,059
INTEREST EXPENSE
Interest Expense, Debt	6,962	7,635	13,991	14,275
Allowance for borrowed funds used during construction	(167)	(985)	(283)	(2,180)
TOTAL	6,795	6,650	13,708	12,095
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	6,436	3,211	9,116	11,657
Income taxes	1,805	(1,718)	2,714	(4,458)
Consolidated net income	4,631	4,929	6,402	16,115
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	159,761	134,899	298,909	258,330
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	18,979	12,444	49,166	38,315
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	57,177	57,985	125,847	114,452
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	430,434	372,194	910,654	711,530
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	64,031	47,790	176,427	89,136
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	70,815	60,527	133,770	119,460
Taxes, Other	20,671	20,524	42,546	39,796
Other Depreciation and Amortization	53,587	43,835	104,523	86,401
Other regulatory charges (credits) - net	25,253	18,724	41,093	40,092
Costs and Expenses	363,056	315,751	768,420	619,027
OPERATING INCOME	67,378	56,443	142,234	92,503
OTHER INCOME
Allowance for equity funds used during construction	2,670	11,601	5,115	22,242
Investment Income, Net	204	343	428	772
Miscellaneous - net	(527)	(791)	(950)	(1,137)
TOTAL	2,347	11,153	4,593	21,877
INTEREST EXPENSE
Interest Expense, Debt	21,899	23,137	44,937	45,995
Allowance for borrowed funds used during construction	(1,075)	(4,985)	(2,059)	(9,558)
TOTAL	20,824	18,152	42,878	36,437
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	48,901	49,444	103,949	77,943
Income taxes	4,111	2,576	9,101	(1,632)
Consolidated net income	44,790	46,868	94,848	79,575
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	471	471	941	941
Earnings (loss) per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	44,319	46,397	93,907	78,634
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	430,434	372,194	910,654	711,530
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Texas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	128,699	124,351	270,061	244,142
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	14,073	6,008	30,932	19,151
Nuclear refueling outage expenses	6,792	5,666	13,510	13,938
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	58,047	42,802	100,007	83,273
Decommissioning	9,625	9,248	19,154	18,405
Taxes, Other	6,968	7,105	13,793	15,078
Other Depreciation and Amortization	25,768	27,501	53,962	54,400
Other regulatory charges (credits) - net	(17,550)	(3,517)	(6,000)	(14,077)
Costs and Expenses	103,723	94,813	225,358	190,168
OPERATING INCOME	57,590	31,236	53,701	66,545
OTHER INCOME
Allowance for equity funds used during construction	1,355	3,200	2,466	6,784
Investment Income, Net	(2,410)	12,108	25,032	17,446
Miscellaneous - net	(7,886)	(2,157)	(9,910)	(4,617)
TOTAL	(8,941)	13,151	17,588	19,613
INTEREST EXPENSE
Interest Expense, Debt	9,579	8,534	19,114	17,074
Allowance for borrowed funds used during construction	(229)	(634)	(417)	(1,345)
TOTAL	9,350	7,900	18,697	15,729
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	39,299	36,487	52,592	70,429
Income taxes	8,969	7,496	(1,602)	12,925
Consolidated net income	30,330	28,991	54,194	57,504
Earnings (loss) per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	30,330	28,991	54,194	57,504
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 161,313	$ 126,049	$ 279,059	$ 256,713

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
OPERATING ACTIVITIES
Consolidated net income	$ 337,750	$ 488,406
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	1,150,294	1,131,212
Deferred income taxes, investment tax credits, and non-current taxes accrued	115,274	68,332
Impairment of Long-Lived Assets Held-for-use	345,339	11,735
Changes in working capital:
Receivables	(154,277)	(30,990)
Fuel inventory	16,718	(19,897)
Accounts payable	(131,414)	(39,054)
Taxes accrued	(69,711)	44,469
Interest accrued	(162)	4,188
Deferred fuel costs	(286,116)	33,298
Other working capital accounts	(86,774)	(63,943)
Changes in provisions for estimated losses	(54,278)	(37,968)
Changes in other regulatory assets	93,776	74,610
Increase (Decrease) in Regulatory Liabilities	170,932	(164,158)
Changes in pension and other postretirement liabilities	(259,593)	(177,224)
Other Noncash Income (Expense)	(441,211)	125,291
Net cash flow provided by operating activities	746,547	1,448,307
INVESTING ACTIVITIES
Construction/capital expenditures	(2,883,376)	(2,185,294)
Allowance for equity funds used during construction	31,449	64,324
Proceeds from Sale of Productive Assets	22,421	0
Nuclear fuel purchases	(73,858)	(113,592)
Payments for Nuclear Fuel	(73,858)	(113,592)
Payments to storm reserve escrow account	(17)	(1,965)
Receipts from storm reserve escrow account	44,205	40,589
Decrease in other investments	10,753	2,262
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	15,735	67,252
Proceeds from nuclear decommissioning trust fund sales	3,837,482	1,249,548
Investment in nuclear decommissioning trust funds	(3,804,170)	(1,309,209)
Changes in securitization account	9,685	12,525
Net cash flow used in investing activities	(2,826,225)	(2,198,193)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	5,008,330	5,201,010
Proceeds from Sale of Treasury Stock	4,039	41,753
Proceeds from Issuance of Common Stock	26,817	0
Retirement of long-term debt	(2,900,566)	(3,592,919)
Changes in credit borrowings and commercial paper - net	(761,244)	(508)
Dividends paid:
Common stock	(381,224)	(371,914)
Other	20,467	(8,448)
Net cash flow provided by financing activities	1,007,460	1,259,632
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(1,072,218)	509,746
Cash and cash equivalents at beginning of period	1,759,099	425,722
Cash and cash equivalents at end of period	686,881	935,468
Cash paid / (received) during the period for:
Interest - net of amount capitalized	428,301	405,248
Income taxes	27,488	(10,007)
Dividends Paid, Preferred Stock	(9,159)	(9,342)
Payments to Acquire Productive Assets	36,534	24,633
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	149,630	104,765
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	252,537	243,126
Deferred income taxes, investment tax credits, and non-current taxes accrued	50,780	24,970
Changes in working capital:
Receivables	(86,447)	(10,360)
Fuel inventory	12,996	(12,704)
Accounts payable	27,920	(34,009)
Taxes accrued	(6,529)	(409)
Interest accrued	(2,490)	119
Deferred fuel costs	(74,857)	16,322
Other working capital accounts	(36,703)	(23,858)
Changes in provisions for estimated losses	(6,122)	998
Changes in other regulatory assets	32,837	(26,191)
Increase (Decrease) in Regulatory Liabilities	17,776	(50,637)
Changes in pension and other postretirement liabilities	(46,940)	(419)
Other Noncash Income (Expense)	(119,755)	55,318
Net cash flow provided by operating activities	164,633	287,031
INVESTING ACTIVITIES
Construction/capital expenditures	(322,044)	(406,940)
Allowance for equity funds used during construction	6,601	6,795
Payments to Acquire Buildings	0	(5,988)
Nuclear fuel purchases	(25,466)	(57,781)
Payments for Nuclear Fuel	(25,466)	(57,781)
Proceeds from sale of nuclear fuel	16,239	18,107
Change in money pool receivable - net	(5,086)	0
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	0	55,001
Proceeds from nuclear decommissioning trust fund sales	227,807	183,474
Investment in nuclear decommissioning trust funds	(224,757)	(194,776)
Changes in securitization account	0	1,244
Net cash flow used in investing activities	(326,706)	(400,864)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	694,137	335,902
Retirement of long-term debt	(618,511)	(226,366)
Change in money pool payable - net	0	4,231
Dividends paid:
Other	19,445	(880)
Net cash flow provided by financing activities	95,071	112,887
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(67,002)	(946)
Cash and cash equivalents at beginning of period	192,128	3,519
Cash and cash equivalents at end of period	125,126	2,573
Cash paid / (received) during the period for:
Interest - net of amount capitalized	70,700	69,276
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	310,553	359,855
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	402,106	392,286
Deferred income taxes, investment tax credits, and non-current taxes accrued	90,537	(1,353)
Changes in working capital:
Receivables	(66,281)	(38,175)
Fuel inventory	(1,240)	(2,233)
Accounts payable	25,685	(37,576)
Taxes accrued	54,850	91,662
Interest accrued	2,162	3,689
Deferred fuel costs	(96,429)	(763)
Other working capital accounts	(36,605)	(13,069)
Changes in provisions for estimated losses	(291)	(38,621)
Changes in other regulatory assets	(124,939)	48,536
Increase (Decrease) in Regulatory Liabilities	87,823	(42,203)
Changes in pension and other postretirement liabilities	(43,936)	(34,280)
Other Noncash Income (Expense)	(84,588)	39,034
Net cash flow provided by operating activities	519,407	726,789
INVESTING ACTIVITIES
Construction/capital expenditures	(1,655,993)	(690,049)
Allowance for equity funds used during construction	12,936	20,942
Payments to Acquire Buildings	0	(14,511)
Nuclear fuel purchases	(63,479)	(24,086)
Payments for Nuclear Fuel	(63,479)	(24,086)
Proceeds from sale of nuclear fuel	0	35,041
Change in money pool receivable - net	(90,225)	(87,635)
Payments to storm reserve escrow account	0	(1,398)
Receipts from storm reserve escrow account	0	40,589
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	0	5,090
Proceeds from nuclear decommissioning trust fund sales	459,326	223,736
Investment in nuclear decommissioning trust funds	(498,332)	(240,559)
Changes in securitization account	(956)	755
Net cash flow used in investing activities	(1,836,723)	(732,085)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	2,097,214	1,401,887
Retirement of long-term debt	(1,296,875)	(826,456)
Change in money pool payable - net	0	(82,826)
Dividends paid:
Common stock	0	(16,500)
Other	(4,169)	(9,080)
Net cash flow provided by financing activities	796,170	467,025
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(521,146)	461,729
Cash and cash equivalents at beginning of period	728,020	2,006
Cash and cash equivalents at end of period	206,874	463,735
Cash paid / (received) during the period for:
Interest - net of amount capitalized	165,480	157,926
Income taxes	0	(20,684)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	77,388	61,419
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	111,194	103,451
Deferred income taxes, investment tax credits, and non-current taxes accrued	33,499	13,126
Changes in working capital:
Receivables	(9,164)	7,076
Fuel inventory	954	(5,747)
Accounts payable	38,287	9,943
Taxes accrued	(49,438)	(34,195)
Interest accrued	(4,623)	1,399
Deferred fuel costs	(46,714)	(2,840)
Other working capital accounts	(27,684)	135
Changes in provisions for estimated losses	(7,860)	(1,782)
Changes in other regulatory assets	(13,050)	(28,290)
Increase (Decrease) in Regulatory Liabilities	13,520	(11,548)
Changes in pension and other postretirement liabilities	(10,086)	(5,353)
Other Noncash Income (Expense)	15,413	5,628
Net cash flow provided by operating activities	121,636	112,422
INVESTING ACTIVITIES
Construction/capital expenditures	(327,163)	(267,231)
Allowance for equity funds used during construction	3,697	3,027
Payments to Acquire Buildings	0	(28,612)
Change in money pool receivable - net	0	31,382
Decrease in other investments	6	(163)
Net cash flow used in investing activities	(323,460)	(261,597)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	200,543	165,408
Change in money pool payable - net	482	0
Dividends paid:
Common stock	0	(2,500)
Other	792	4,850
Net cash flow provided by financing activities	201,817	167,758
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(7)	18,583
Cash and cash equivalents at beginning of period	18	51,601
Cash and cash equivalents at end of period	11	70,184
Cash paid / (received) during the period for:
Interest - net of amount capitalized	39,925	31,196
Income taxes	(8,045)	0
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	6,402	16,115
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	36,314	30,701
Deferred income taxes, investment tax credits, and non-current taxes accrued	4,907	1,228
Changes in working capital:
Receivables	(15,306)	5,255
Fuel inventory	725	1,042
Accounts payable	(7,309)	(1,725)
Taxes accrued	948	1,887
Interest accrued	(1,315)	529
Deferred fuel costs	4,423	3,351
Other working capital accounts	(11,944)	(19,793)
Changes in provisions for estimated losses	(40,152)	1,521
Changes in other regulatory assets	35,038	3,508
Increase (Decrease) in Regulatory Liabilities	4,823	(14,151)
Changes in pension and other postretirement liabilities	(7,352)	(7,523)
Other Noncash Income (Expense)	16,986	2,715
Net cash flow provided by operating activities	27,188	24,660
INVESTING ACTIVITIES
Construction/capital expenditures	(94,173)	(114,961)
Allowance for equity funds used during construction	634	4,533
Payments to Acquire Buildings	0	(1,584)
Change in money pool receivable - net	0	(586)
Payments to storm reserve escrow account	(7)	(405)
Receipts from storm reserve escrow account	44,200	0
Changes in securitization account	686	451
Net cash flow used in investing activities	(48,660)	(112,552)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	138,939
Retirement of long-term debt	(5,749)	(25,616)
Change in money pool payable - net	27,684	0
Dividends paid:
Other	(463)	(703)
Net cash flow provided by financing activities	21,472	112,620
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	0	24,728
Cash and cash equivalents at beginning of period	26	6,017
Cash and cash equivalents at end of period	26	30,745
Cash paid / (received) during the period for:
Interest - net of amount capitalized	14,684	13,132
Income taxes	324	3,332
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	94,848	79,575
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	104,523	86,401
Deferred income taxes, investment tax credits, and non-current taxes accrued	5,237	9,470
Changes in working capital:
Receivables	(33,522)	(20,524)
Fuel inventory	3,606	1,222
Accounts payable	1,530	(3,543)
Taxes accrued	(4,057)	(11,390)
Interest accrued	(1,072)	359
Deferred fuel costs	(72,537)	17,226
Other working capital accounts	(3,285)	9,928
Changes in provisions for estimated losses	314	91
Changes in other regulatory assets	43,619	50,347
Increase (Decrease) in Regulatory Liabilities	(2,036)	(23,947)
Changes in pension and other postretirement liabilities	(11,050)	(13,825)
Other Noncash Income (Expense)	(6,583)	(10,842)
Net cash flow provided by operating activities	119,535	170,548
INVESTING ACTIVITIES
Construction/capital expenditures	(401,362)	(495,560)
Allowance for equity funds used during construction	5,115	22,242
Proceeds from Sale of Productive Assets	67,920	0
Change in money pool receivable - net	4,601	3,379
Changes in securitization account	9,955	10,075
Net cash flow used in investing activities	(350,305)	(464,795)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	194,256
Retirement of long-term debt	(170,429)	(43,376)
Change in money pool payable - net	63,437	0
Dividends paid:
Other	5,132	(1,199)
Net cash flow provided by financing activities	(17,801)	323,557
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(248,571)	29,310
Cash and cash equivalents at beginning of period	248,596	12,929
Cash and cash equivalents at end of period	25	42,239
Cash paid / (received) during the period for:
Interest - net of amount capitalized	44,760	44,683
Income taxes	9,710	4,031
Proceeds from Contributions from Parent	85,000	175,000
Dividends Paid, Preferred Stock	(941)	(1,124)
Payments to Acquire Productive Assets	36,534	4,931
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	54,194	57,504
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	101,640	88,343
Deferred income taxes, investment tax credits, and non-current taxes accrued	(3,052)	517
Changes in working capital:
Receivables	(15,877)	18,213
Accounts payable	(3,449)	(18,591)
Taxes accrued	(27,698)	6,020
Interest accrued	(1,102)	(12)
Other working capital accounts	442	(41,850)
Changes in other regulatory assets	60,949	(21,072)
Increase (Decrease) in Regulatory Liabilities	49,033	(21,672)
Changes in pension and other postretirement liabilities	(12,243)	(5,354)
Other Noncash Income (Expense)	(158,386)	22,690
Net cash flow provided by operating activities	44,451	84,736
INVESTING ACTIVITIES
Construction/capital expenditures	(38,268)	(147,889)
Allowance for equity funds used during construction	2,466	6,784
Nuclear fuel purchases	(11,039)	(75,024)
Payments for Nuclear Fuel	(11,039)	(75,024)
Proceeds from sale of nuclear fuel	12,754	9,573
Change in money pool receivable - net	(56,107)	59,298
Proceeds from nuclear decommissioning trust fund sales	418,042	275,563
Investment in nuclear decommissioning trust funds	(414,525)	(286,018)
Net cash flow used in investing activities	(86,677)	(157,713)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	453,981	482,533
Retirement of long-term debt	(509,002)	(434,104)
Change in money pool payable - net	0	15,774
Dividends paid:
Common stock	(26,000)	(59,653)
Net cash flow provided by financing activities	(81,021)	4,550
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	(123,247)	(68,427)
Cash and cash equivalents at beginning of period	242,469	68,534
Cash and cash equivalents at end of period	119,222	107
Cash paid / (received) during the period for:
Interest - net of amount capitalized	29,231	8,589
Income taxes	$ 39,085	$ (4,000)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2021	May 01, 2021	Dec. 31, 2020	Jun. 30, 2020	Dec. 31, 2019
Cash and cash equivalents:
Cash	$ 157,265		$ 128,851
Temporary cash investments	529,616		1,630,248
Total cash and cash equivalents	686,881		1,759,099	$ 935,468	$ 425,722
Securitization recovery trust account	33,000		42,000
Accounts receivable:
Customer	877,221		833,478
Allowance for doubtful accounts	(109,189)		(117,794)
Other	158,262		135,208
Accrued unbilled revenues	513,710		434,835
Total accounts receivable	1,440,004		1,285,727
Deferred Fuel Cost	152,230		4,380
Fuel inventory - at average cost	156,216		172,934
Public Utilities, Inventory	990,088		962,185
Deferred nuclear refueling outage costs	173,365		179,150
Prepaid Expense and Other Assets, Current	195,922		196,424
TOTAL	3,794,706		4,559,899
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	5,238,727		7,253,215
Non-utility property - at cost (less accumulated depreciation)	353,423		343,328
Other	156,766		214,222
TOTAL	5,748,916		7,810,765
PROPERTY, PLANT, AND EQUIPMENT
Electric	61,064,428		59,696,443
Natural gas	631,471		610,768
Construction work in progress	1,383,758		2,012,030
Nuclear fuel	549,166		601,281
TOTAL PROPERTY, PLANT, AND EQUIPMENT	63,628,823		62,920,522
Less - accumulated depreciation and amortization	24,197,413		24,067,745
PROPERTY, PLANT, AND EQUIPMENT - NET	39,431,410		38,852,777
Regulatory assets:
Other regulatory assets	5,982,773		6,076,549
Deferred Fuel Cost Non Current	240,688		240,422
Goodwill	377,172		377,172
Deferred Income Tax Assets, Net	60,749		76,289
Other	312,869		245,339
Deferred Costs and Other Assets	6,974,251		7,015,771
TOTAL ASSETS	55,949,283		58,239,212
CURRENT LIABILITIES
Currently maturing long-term debt	285,324		1,164,015
Short-term borrowings	866,245		1,627,489
Accounts payable	1,348,734		2,739,437
Taxes Payable, Current	371,300		441,011
Interest accrued	201,629		201,791
Deferred fuel costs	15,111		153,113
Pension and other postretirement liabilities	67,963		61,815
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	64,288		63,683
Other	193,640		206,640
TOTAL	3,804,540		7,060,506
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,375,535		4,361,772
Accumulated deferred investment tax credits	215,828		212,494
Regulatory liability for income taxes - net	1,435,112		1,521,757
Other regulatory liabilities	2,580,823		2,323,851
Decommissioning and asset retirement cost liabilities	4,635,300		6,469,452
Loss Contingency Accrual	188,557		242,835
Pension and other postretirement liabilities	2,587,272		2,853,013
Long-term debt	24,211,966		21,205,761
Deferred Credits and Other Liabilities	771,993		807,219
TOTAL	$ 41,002,386		$ 39,998,154
Common Stock, Shares, Issued	270,300,648		270,035,180
Subsidiaries' preferred stock without sinking fund	$ 219,410		$ 219,410
Preferred Stock, Shares Issued	0		0
Proceeds from Issuance of Preferred Stock and Preference Stock	$ 0		$ 0
Preferred Stock, Shares Authorized	1,000,000	1,000,000	0
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 2,703		$ 2,700
Additional Paid in Capital, Common Stock	6,561,676		6,549,923
Accumulated other comprehensive loss	$ (478,739)		$ (449,207)	(388,604)	(446,920)
Treasury Stock, Shares	69,347,286		69,790,346
Less - treasury stock, at cost	$ 5,042,242		$ 5,074,456
TOTAL	10,887,947		10,926,142
Stockholders' Equity Attributable to Noncontrolling Interest	35,000		35,000
Retained Earnings (Accumulated Deficit)	9,844,549		9,897,182
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	10,922,947		10,961,142	10,460,988	10,258,675
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	55,949,283		58,239,212
Long-term Transition Bond, Noncurrent	$ 113,572		$ 174,635
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01	$ 0.01
Securitized Regulatory Transition Assets, Noncurrent	$ 83,195		$ 119,238
Contract with Customer, Liability, Current	$ 390,306		$ 401,512
Common Stock, Shares Authorized	499,000,000	499,000,000	499,000,000
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	$ 108,882		$ 24,108
Temporary cash investments	16,244		168,020
Total cash and cash equivalents	125,126		192,128	2,573	3,519
Accounts receivable:
Customer	208,469		183,719
Allowance for doubtful accounts	(22,395)		(18,334)
Associated companies	48,646		34,216
Other	64,661		35,845
Accrued unbilled revenues	136,598		109,000
Total accounts receivable	435,979		344,446
Deferred Fuel Cost	21,527		0
Fuel inventory - at average cost	30,815		43,811
Public Utilities, Inventory	247,633		237,640
Deferred nuclear refueling outage costs	46,996		32,692
Prepaid Expense and Other Assets, Current	20,228		13,296
TOTAL	928,304		864,013
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,376,715		1,273,921
Other	339		341
TOTAL	1,377,054		1,274,262
PROPERTY, PLANT, AND EQUIPMENT
Electric	13,067,828		12,905,322
Construction work in progress	319,379		234,213
Nuclear fuel	156,819		163,044
TOTAL PROPERTY, PLANT, AND EQUIPMENT	13,544,026		13,302,579
Less - accumulated depreciation and amortization	5,384,637		5,255,355
PROPERTY, PLANT, AND EQUIPMENT - NET	8,159,389		8,047,224
Regulatory assets:
Other regulatory assets	1,799,547		1,832,384
Deferred Fuel Cost Non Current	68,485		68,220
Other	17,292		14,028
Deferred Costs and Other Assets	1,885,324		1,914,632
TOTAL ASSETS	12,350,071		12,100,131
CURRENT LIABILITIES
Currently maturing long-term debt	90,000		485,000
Associated companies accounts payable	94,710		59,448
Accounts payable	183,266		208,591
Taxes Payable, Current	75,308		81,837
Interest accrued	20,255		22,745
Deferred fuel costs	0		53,065
Other	41,682		40,628
TOTAL	597,695		1,049,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,346,301		1,286,123
Accumulated deferred investment tax credits	29,899		30,500
Regulatory liability for income taxes - net	446,059		467,031
Other regulatory liabilities	725,620		686,872
Decommissioning and asset retirement cost liabilities	1,352,440		1,314,160
Loss Contingency Accrual	64,047		70,169
Pension and other postretirement liabilities	314,639		361,682
Long-term debt	3,953,714		3,482,507
Deferred Credits and Other Liabilities	93,858		75,098
TOTAL	8,326,577		7,774,142
Common Shareholders' Equity:
Members' Equity	3,425,799		3,276,169
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	3,425,799		3,276,169	3,230,702	3,125,937
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	12,350,071		12,100,131
Contract with Customer, Liability, Current	92,474		98,506
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	231		1,303
Temporary cash investments	206,643		726,717
Total cash and cash equivalents	206,874		728,020	463,735	2,006
Securitization recovery trust account	3,700		2,700
Accounts receivable:
Customer	336,478		317,905
Allowance for doubtful accounts	(39,793)		(45,693)
Associated companies	191,251		81,624
Other	36,096		41,760
Accrued unbilled revenues	206,910		178,840
Total accounts receivable	730,942		574,436
Deferred Fuel Cost	98,679		2,250
Fuel inventory - at average cost	51,920		50,680
Public Utilities, Inventory	443,275		437,933
Deferred nuclear refueling outage costs	63,843		48,407
Prepaid Expense and Other Assets, Current	51,441		36,813
TOTAL	1,646,974		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	1,985,477		1,794,042
Non-utility property - at cost (less accumulated depreciation)	333,392		323,110
Other	13,500		13,399
TOTAL	3,722,956		3,521,138
PROPERTY, PLANT, AND EQUIPMENT
Electric	26,204,300		25,619,789
Natural gas	271,712		262,744
Construction work in progress	577,975		667,281
Nuclear fuel	224,870		210,128
TOTAL PROPERTY, PLANT, AND EQUIPMENT	27,278,857		26,759,942
Less - accumulated depreciation and amortization	9,610,279		9,372,224
PROPERTY, PLANT, AND EQUIPMENT - NET	17,668,578		17,387,718
Regulatory assets:
Other regulatory assets	1,851,005		1,726,066
Deferred Fuel Cost Non Current	168,122		168,122
Other	33,094		23,924
Deferred Costs and Other Assets	2,052,221		1,918,112
TOTAL ASSETS	25,090,729		24,705,507
CURRENT LIABILITIES
Currently maturing long-term debt	0		240,000
Associated companies accounts payable	116,333		103,148
Accounts payable	476,177		1,450,008
Taxes Payable, Current	97,467		42,617
Interest accrued	94,411		92,249
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	31,138		31,138
Other	62,057		62,968
TOTAL	1,028,636		2,174,740
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,230,734		2,138,522
Accumulated deferred investment tax credits	104,953		107,317
Regulatory liability for income taxes - net	425,192		447,628
Other regulatory liabilities	1,028,552		918,293
Decommissioning and asset retirement cost liabilities	1,612,748		1,573,307
Loss Contingency Accrual	24,648		24,939
Pension and other postretirement liabilities	648,825		692,728
Long-term debt	9,836,133		8,787,451
Deferred Credits and Other Liabilities	381,914		382,894
TOTAL	16,293,699		15,073,079
Common Shareholders' Equity:
Accumulated other comprehensive loss	4,508		4,327
Members' Equity	7,763,886		7,453,361
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	7,768,394		7,457,688	6,748,972	6,397,118
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	25,090,729		24,705,507
Long-term Transition Bond, Noncurrent	0		10,278
Securitized Regulatory Transition Assets, Noncurrent	0		5,088
Contract with Customer, Liability, Current	151,053		152,612
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	11		11
Temporary cash investments	0		7
Total cash and cash equivalents	11		18	70,184	51,601
Accounts receivable:
Customer	91,479		105,732
Allowance for doubtful accounts	(13,646)		(19,527)
Associated companies	4,226		2,740
Other	15,985		11,821
Accrued unbilled revenues	71,400		59,514
Total accounts receivable	169,444		160,280
Deferred Fuel Cost	32,023		0
Fuel inventory - at average cost	16,163		17,117
Public Utilities, Inventory	65,915		59,542
Prepaid Expense and Other Assets, Current	22,447		4,876
TOTAL	306,003		241,833
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,535		4,543
Escrow accounts	48,932		64,635
TOTAL	53,467		69,178
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,275,518		6,084,730
Construction work in progress	172,783		134,854
TOTAL PROPERTY, PLANT, AND EQUIPMENT	6,448,301		6,219,584
Less - accumulated depreciation and amortization	2,068,644		2,005,087
PROPERTY, PLANT, AND EQUIPMENT - NET	4,379,657		4,214,497
Regulatory assets:
Other regulatory assets	480,391		467,341
Other	16,239		14,413
Deferred Costs and Other Assets	496,630		481,754
TOTAL ASSETS	5,235,757		5,007,262
CURRENT LIABILITIES
Associated companies accounts payable	64,309		61,727
Accounts payable	118,387		117,629
Taxes Payable, Current	58,646		108,084
Interest accrued	16,266		20,889
Deferred fuel costs	0		14,691
Other	23,075		34,270
TOTAL	366,711		443,490
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	680,901		646,674
Accumulated deferred investment tax credits	11,025		9,062
Regulatory liability for income taxes - net	219,343		224,000
Other regulatory liabilities	34,005		15,828
Decommissioning and asset retirement cost liabilities	10,035		9,762
Loss Contingency Accrual	38,644		46,504
Pension and other postretirement liabilities	100,700		110,901
Long-term debt	1,981,674		1,780,577
Deferred Credits and Other Liabilities	42,597		47,730
TOTAL	3,118,924		2,891,038
Common Shareholders' Equity:
Members' Equity	1,750,122		1,672,734
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,750,122		1,672,734	1,601,070	1,542,151
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	5,235,757		5,007,262
Contract with Customer, Liability, Current	86,028		86,200
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26		26
Total cash and cash equivalents	26		26	30,745	6,017
Securitization recovery trust account	2,678		3,364
Accounts receivable:
Customer	86,901		70,694
Allowance for doubtful accounts	(21,132)		(17,430)
Associated companies	1,406		2,381
Other	8,944		4,248
Accrued unbilled revenues	30,149		31,069
Total accounts receivable	106,268		90,962
Deferred Fuel Cost	0		2,130
Fuel inventory - at average cost	1,253		1,978
Public Utilities, Inventory	16,034		16,550
Prepaid Expense and Other Assets, Current	16,257		3,715
TOTAL	142,516		118,725
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016		1,016
Storm Reserve Escrow Account	38,846		83,038
TOTAL	39,862		84,054
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,825,128		1,821,638
Natural gas	359,759		348,024
Construction work in progress	29,053		12,460
TOTAL PROPERTY, PLANT, AND EQUIPMENT	2,213,940		2,182,122
Less - accumulated depreciation and amortization	755,956		740,796
PROPERTY, PLANT, AND EQUIPMENT - NET	1,457,984		1,441,326
Regulatory assets:
Other regulatory assets	231,752		266,790
Deferred Fuel Cost Non Current	4,080		4,080
Other	32,970		23,931
Deferred Costs and Other Assets	268,802		294,801
TOTAL ASSETS	1,909,164		1,938,906
CURRENT LIABILITIES
Currently maturing long-term debt	70,000		0
Notes Payable, Related Parties, Current	1,618		1,618
Associated companies accounts payable	77,066		54,234
Accounts payable	34,389		60,766
Taxes Payable, Current	5,648		4,700
Interest accrued	6,780		8,095
Deferred fuel costs	2,293		0
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	3,295		3,296
Other	6,279		5,462
TOTAL	234,681		166,083
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	343,485		338,714
Accumulated deferred investment tax credits	16,067		16,095
Regulatory liability for income taxes - net	54,637		55,675
Decommissioning and asset retirement cost liabilities	3,898		3,768
Loss Contingency Accrual	49,746		89,898
Long-term debt	554,341		629,704
Notes Payable, Related Parties, Noncurrent	10,911		10,911
Deferred Credits and Other Liabilities	28,079		21,141
TOTAL	1,061,164		1,165,906
Common Shareholders' Equity:
Members' Equity	613,319		606,917
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	613,319		606,917	513,694	497,579
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,909,164		1,938,906
Long-term Transition Bond, Noncurrent	35,664		41,291
Securitized Regulatory Transition Assets, Noncurrent	30,995		35,559
Contract with Customer, Liability, Current	27,313		27,912
Entergy Texas [Member]
Cash and cash equivalents:
Cash	25		26
Temporary cash investments	0		248,570
Total cash and cash equivalents	25		248,596	42,239	12,929
Securitization recovery trust account	26,278		36,233
Accounts receivable:
Customer	111,163		103,221
Allowance for doubtful accounts	(12,223)		(16,810)
Associated companies	17,494		18,892
Other	17,328		11,780
Accrued unbilled revenues	68,654		56,411
Total accounts receivable	202,416		173,494
Fuel inventory - at average cost	49,925		53,531
Public Utilities, Inventory	63,417		56,227
Prepaid Expense and Other Assets, Current	15,055		20,165
TOTAL	357,116		588,246
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	324		349
Non-utility property - at cost (less accumulated depreciation)	376		376
Other	17,744		19,889
TOTAL	18,444		20,614
PROPERTY, PLANT, AND EQUIPMENT
Electric	6,918,133		6,007,687
Construction work in progress	181,473		879,908
TOTAL PROPERTY, PLANT, AND EQUIPMENT	7,099,606		6,887,595
Less - accumulated depreciation and amortization	1,981,761		1,864,494
PROPERTY, PLANT, AND EQUIPMENT - NET	5,117,845		5,023,101
Regulatory assets:
Other regulatory assets	481,094		524,713
Other	81,501		70,397
Deferred Costs and Other Assets	562,595		595,110
TOTAL ASSETS	6,056,000		6,227,071
CURRENT LIABILITIES
Currently maturing long-term debt	75,000		200,000
Associated companies accounts payable	110,028		55,944
Accounts payable	179,398		350,947
Taxes Payable, Current	48,381		52,438
Interest accrued	19,784		20,856
Deferred fuel costs	12,819		85,356
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	29,855		29,249
Other	14,303		12,370
TOTAL	523,005		843,442
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	647,348		639,422
Accumulated deferred investment tax credits	9,634		9,942
Regulatory liability for income taxes - net	157,086		175,594
Other regulatory liabilities	48,163		32,297
Decommissioning and asset retirement cost liabilities	8,288		8,063
Loss Contingency Accrual	8,696		8,382
Long-term debt	2,248,879		2,293,708
Deferred Credits and Other Liabilities	68,416		58,643
TOTAL	$ 3,196,510		$ 3,226,051
Common Stock, Shares, Outstanding	46,525,000		46,525,000
Common Stock, Shares, Issued	46,525,000		46,525,000
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 49,452		$ 49,452
Additional Paid in Capital, Common Stock	1,040,162		955,162
TOTAL	2,301,485		2,122,578
Stockholders' Equity Attributable to Noncontrolling Interest	35,000		35,000
Retained Earnings (Accumulated Deficit)	1,211,871		1,117,964
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,336,485		2,157,578	2,053,031	1,799,407
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	6,056,000		6,227,071
Long-term Transition Bond, Noncurrent	77,908		123,066
Securitized Regulatory Transition Assets, Noncurrent	52,330		78,590
Contract with Customer, Liability, Current	$ 33,437		$ 36,282
Common Stock, Shares Authorized	200,000,000		200,000,000
System Energy [Member]
Cash and cash equivalents:
Cash	$ 139		$ 26,086
Temporary cash investments	119,083		216,383
Total cash and cash equivalents	119,222		242,469	107	68,534
Accounts receivable:
Associated companies	127,194		57,743
Other	5,083		2,550
Total accounts receivable	132,277		60,293
Public Utilities, Inventory	136,428		123,006
Deferred nuclear refueling outage costs	21,314		34,459
Prepaid Expense and Other Assets, Current	6,143		6,864
TOTAL	415,384		467,091
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,312,525		1,215,868
TOTAL	1,312,525		1,215,868
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,321,319		5,309,458
Construction work in progress	75,019		59,831
Nuclear fuel	133,364		175,005
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,529,702		5,544,294
Less - accumulated depreciation and amortization	3,351,715		3,355,367
PROPERTY, PLANT, AND EQUIPMENT - NET	2,177,987		2,188,927
Regulatory assets:
Other regulatory assets	478,014		538,963
Other	2,277		3,119
Deferred Costs and Other Assets	480,291		542,082
TOTAL ASSETS	4,386,187		4,413,968
CURRENT LIABILITIES
Currently maturing long-term debt	50,324		100,015
Associated companies accounts payable	18,825		15,309
Accounts payable	38,862		41,313
Taxes Payable, Current	55,279		82,977
Interest accrued	11,620		12,722
Other	4,246		4,248
TOTAL	179,156		256,584
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	349,912		359,835
Accumulated deferred investment tax credits	43,643		38,902
Regulatory liability for income taxes - net	132,794		151,829
Other regulatory liabilities	733,464		665,396
Decommissioning and asset retirement cost liabilities	988,064		968,910
Pension and other postretirement liabilities	113,169		125,412
Long-term debt	700,615		705,259
Deferred Credits and Other Liabilities	36,630		61,295
TOTAL	$ 3,098,291		$ 3,076,838
Common Stock, Shares, Outstanding	789,350		789,350
Common Stock, Shares, Issued	789,350		789,350
Common Shareholders' Equity:
Common Stock, Value, Issued	$ 951,850		$ 951,850
Retained Earnings (Accumulated Deficit)	156,890		128,696
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,108,740		1,080,546	$ 709,919	$ 712,068
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 4,386,187		$ 4,413,968
Common Stock, Shares Authorized	1,000,000		1,000,000

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Net income	$ (1,394)	$ 365,113	$ 337,750	$ 488,406
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(222)	(25,406)	(29,802)	(47,116)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	22,098	17,224	45,065	71,123
Net unrealized investment gains	(108)	18,565	(44,795)	34,309
Other comprehensive income (loss)	21,768	10,383	(29,532)	58,316
Total comprehensive income	20,374	375,496	308,218	546,722
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580	4,580	9,159	9,159
Comprehensive Income Attributable to Entergy Corporation	15,794	370,916	299,059	537,563
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	6,231	4,713	12,545	19,789
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	(27)	10,812	(25,608)	19,555
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	66	6,760	7,935	12,537
Entergy Louisiana [Member]
Net income	143,927	170,459	310,553	359,855
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	588	(945)	181	8,522
Other comprehensive income (loss)	588	(945)	181	8,522
Total comprehensive income	144,515	169,514	310,734	368,377
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	208	(334)	64	3,006
Entergy Arkansas [Member]
Net income	56,593	60,170	149,630	104,765
System Energy [Member]
Net income	$ 30,330	$ 28,991	$ 54,194	$ 57,504

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total	Subsidiaries Preferred Stock [Member]	Paid In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]	Common Stock [Member]	Treasury Stock [Member]	Entergy Texas [Member]	Entergy Texas [Member]Subsidiaries Preferred Stock [Member]	Entergy Texas [Member]Paid In Capital [Member]	Entergy Texas [Member]Retained Earnings [Member]	Entergy Texas [Member]Common Stock [Member]	Entergy Mississippi [Member]	Entergy Arkansas [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member]Member's Equity [Member]	Entergy Louisiana [Member]Accumulated Other Comprehensive Income [Member]	Entergy New Orleans [Member]	System Energy [Member]	System Energy [Member]Retained Earnings [Member]	System Energy [Member]Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,258,675	$ 35,000	$ 6,564,436	$ 9,257,609	$ (446,920)	$ 2,700	$ (5,154,150)	$ 1,799,407	$ 35,000	$ 780,182	$ 934,773	$ 49,452	$ 1,542,151	$ 3,125,937	$ 6,397,118	$ 6,392,556	$ 4,562	$ 497,579	$ 712,068	$ 110,218	$ 601,850
Consolidated net income	123,294	4,580	0	118,714	0	0	0	32,707	0	0	32,707	0	22,526	44,595	189,396	189,396	0	11,186	28,513	28,513	0
Proceeds from Contributions from Parent								175,000	0	175,000	0	0
Dividends, Common Stock, Cash	(185,763)	0	0	(185,763)	0	0	0						(2,500)		(11,500)	(11,500)	0		(13,653)	(13,653)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	47,933	0	0	0	47,933	0	0								9,467	0	9,467
Common stock issuances related to stock plans	(19,827)	0	53,753	0	0	0	(73,580)
Other															(10)	(10)	0
Dividends, Preferred Stock, Cash	4,100							470	0	0	470	0
Consolidated net income	488,406							79,575					61,419	104,765	359,855			16,115	57,504
Proceeds from Contributions from Parent								175,000
Other comprehensive income (loss)	58,316														8,522
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 9,159							941
Stock Options Excluded From Diluted Common Shares Outstanding Calculation	500,000
Common stock dividend (in dollars per share)	$ 1.86
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,258,967	35,000	6,510,683	9,190,141	(398,987)	2,700	(5,080,570)	2,006,644	35,000	955,182	967,010	49,452	1,562,177	3,170,532	6,584,471	6,570,442	14,029	508,765	726,928	125,078	601,850
Consolidated net income	365,113	4,580	0	360,533	0	0	0	46,868	0	0	46,868	0	38,893	60,170	170,459	170,459	0	4,929	28,991	28,991	0
Dividends, Common Stock, Cash	(186,151)	0	0	(186,151)	0	0	0								(5,000)	(5,000)	0		(46,000)	(46,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	10,383	0	0	0	10,383	0	0								(945)	0	(945)
Common stock issuances related to stock plans	(17,256)	0	(13,647)	0	0	0	(3,609)
Other								(10)	0	(10)	0	0			(13)	(13)	0
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580							471
Dividends, Preferred Stock, Cash	$ 4,100							471	0	0	471	0
Stock Options Excluded From Diluted Common Shares Outstanding Calculation	500,000
Common stock dividend (in dollars per share)	$ 0.93
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,460,988	35,000	6,524,330	9,364,523	(388,604)	2,700	(5,076,961)	2,053,031	35,000	955,172	1,013,407	49,452	1,601,070	3,230,702	6,748,972	6,735,888	13,084	513,694	709,919	108,069	601,850
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	10,961,142	35,000	6,549,923	9,897,182	(449,207)	2,700	(5,074,456)	2,157,578	35,000	955,162	1,117,964	49,452	1,672,734	3,276,169	7,457,688	7,453,361	4,327	606,917	1,080,546	128,696	951,850
Consolidated net income	339,145	4,580	0	334,565	0	0	0	50,058	0	0	50,058	0	25,972	93,037	166,626	166,626	0	1,771	23,864	23,864	0
Dividends, Common Stock, Cash	(190,595)	0	0	(190,595)	0	0	0												(21,000)	(21,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	(51,300)	0	0	0	(51,300)	0	0								(407)	0	(407)
Common stock issuances related to stock plans	1,636	0	29,871	0	0	0	(28,235)
Other															(16)	(16)	0
Dividends, Preferred Stock, Cash	4,100							470	0	0	470	0
Consolidated net income	337,750							94,848					77,388	149,630	310,553			6,402	54,194
Proceeds from Contributions from Parent								85,000
Other comprehensive income (loss)	(29,532)														181
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 9,159							941
Stock Options Excluded From Diluted Common Shares Outstanding Calculation	1,000,000
Common stock dividend (in dollars per share)	$ 1.90
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 11,052,176	35,000	6,520,052	10,041,152	(500,507)	2,700	(5,046,221)	2,207,166	35,000	955,162	1,167,552	49,452	1,698,706	3,369,206	7,623,891	7,619,971	3,920	608,688	1,083,410	131,560	951,850
Consolidated net income	(1,394)	4,580	0	(5,974)	0	0	0	44,790	0	0	44,790	0	51,416	56,593	143,927	143,927	0	4,631	30,330	30,330	0
Proceeds from Contributions from Parent								85,000	0	85,000	0	0
Dividends, Common Stock, Cash	(190,629)	0	0	(190,629)	0	0	0												(5,000)	(5,000)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,580)	(4,580)	0	0	0	0	0
Other comprehensive income (loss)	21,768	0	0	0	21,768	0	0								588	0	588
Common stock issuances related to stock plans	(18,789)	0	(14,810)	0	0	0	(3,979)
Other															(12)	(12)	0
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,580							471
Dividends, Preferred Stock, Cash	$ 4,100							471	0	0	471	0
Stock Options Excluded From Diluted Common Shares Outstanding Calculation	1,000,000
Common stock dividend (in dollars per share)	$ 0.95
Equity Distribution Sales Agreement, Aggregate Compensation to Sales Agents [Abstract]
Stock Issued During Period, Value, New Issues	$ 28,216	0	28,213	0	0	3	0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	(1,399)	0	(1,399)	0	0	0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,922,947	$ 35,000	$ 6,561,676	$ 9,844,549	$ (478,739)	$ 2,703	$ (5,042,242)	$ 2,336,485	$ 35,000	$ 1,040,162	$ 1,211,871	$ 49,452	$ 1,750,122	$ 3,425,799	$ 7,768,394	$ 7,763,886	$ 4,508	$ 613,319	$ 1,108,740	$ 156,890	$ 951,850
Shares, Issued	265,468

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2021
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
Entergy Arkansas [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
Entergy Louisiana [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
Entergy Mississippi [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
Entergy New Orleans [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
Entergy Texas [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements
System Energy [Member]
Commitments And Contingencies	NOTE 1. 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 commissions, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 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 $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants. Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements

Rate And Regulatory Matters

Rate And Regulatory Matters	6 Months Ended
	Jun. 30, 2021
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
Entergy Arkansas [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
Entergy Louisiana [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
Entergy Mississippi [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
Entergy New Orleans [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
Entergy Texas [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th
System Energy [Member]
Rate and Regulatory Matters	NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries. The following are updates to that discussion. Fuel and purchased power cost recovery Entergy Arkansas Energy Cost Recovery Rider In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff. Entergy Louisiana In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing. In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed. Entergy Texas In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2020 Formula Rate Plan Filing As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021. 2021 Formula Rate Plan Filing In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021. COVID-19 Orders See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC s taff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. Request for Extension and Modification of Formula Rate Plan As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees. 2020 Formula Rate Plan Filing In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic. Filings with the MPSC (Entergy Mississippi) 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. T hese interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “ COVID-19 Orders ” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation. COVID-19 Orders As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic. Filings with the City Council (Entergy New Orleans) 2021 Formula Rate Plan Filing In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022. COVID-19 Orders As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program. Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic. Filings with the PUCT and Texas Cities (Entergy Texas) Distribution Cost Recovery Factor (DCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement. Transmission Cost Recovery Factor (TCRF) Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement. COVID-19 Orders As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic. Generation Cost Recovery Rider As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge. In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary. Complaints Against System Energy Return on Equity and Capital Structure Complaints As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020. In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximate ly $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process , and an ALJ’s determinations made in an initial decision are not controlling on the FERC . In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision. Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021. The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on th

Equity

Equity	6 Months Ended
	Jun. 30, 2021
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings (Loss) per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings (loss) per share Net income (loss) attributable to Entergy Corporation ($6.0) 200.8 ($0.03) $360.5 200.2 $1.80 Average dilutive effect of: Stock options — — 0.3 — Other equity plans — — 0.4 (0.01) Diluted earnings (loss) per share ($6.0) 200.8 ($0.03) $360.5 200.9 $1.79 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the three months ended June 30, 2021 and approximately 0.5 million for the three months ended June 30, 2020. The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Six Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $328.6 200.7 $1.64 $479.2 200.0 $2.40 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.01) Other equity plans 0.3 — 0.4 — Diluted earnings per share $328.6 201.4 $1.63 $479.2 200.9 $2.39 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the six months ended June 30, 2021 and approximately 0.5 million for the six months ended June 30, 2020. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $0.95 for the three months ended June 30, 2021 and $0.93 for the three months ended June 30, 2020. Dividends declared per common share were $1.90 for the six months ended June 30, 2021 and $1.86 for the six months ended June 30, 2020. 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 six months ended June 30, 2021, Entergy Corporation issued 265,468 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $26.8 million, which includes the gross sales price of $28.2 million received by Entergy Corporation less $1.1 million of general issuance costs and $0.3 million of aggregate compensation to the agents with respect to such sales. In June 2021, Entergy entered into a forward sale agreement for 416,853 shares of common stock. 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 agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares of its common stock to the investment bank in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially $106.87 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million with aggregate compensation to the agents of $0.5 million. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, 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. For the three and six months ended June 30, 2021, shares under the forward sale agreement were not included in the calculation of diluted common shares outstanding because their effect would have been antidilutive. Treasury Stock During the six months ended June 30, 2021, Entergy Corporation issued 443,060 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2021. Retained Earnings On July 30, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on September 1, 2021, to holders of record as of August 12, 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2021 ($861) ($511,609) $11,963 ($500,507) Other comprehensive income (loss) before reclassifications (14) — 648 634 Amounts reclassified from accumulated other comprehensive income (loss) (208) 22,098 (756) 21,134 Net other comprehensive income (loss) for the period (222) 22,098 (108) 21,768 Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2020 $62,496 ($503,173) $41,690 ($398,987) Other comprehensive income (loss) before reclassifications 4,890 — 22,545 27,435 Amounts reclassified from accumulated other comprehensive income (loss) (30,296) 17,224 (3,980) (17,052) Net other comprehensive income (loss) for the period (25,406) 17,224 18,565 10,383 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,467 — (44,653) (43,186) Amounts reclassified from accumulated other comprehensive income (loss) (31,269) 45,065 (142) 13,654 Net other comprehensive income (loss) for the period (29,802) 45,065 (44,795) (29,532) Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 97,373 34,349 40,258 171,980 Amounts reclassified from accumulated other comprehensive income (loss) (144,489) 36,774 (5,949) (113,664) Net other comprehensive income (loss) for the period (47,116) 71,123 34,309 58,316 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, April 1, $3,920 $14,029 Amounts reclassified from accumulated other comprehensive income (loss) 588 (945) Net other comprehensive income (loss) for the period 588 (945) Ending balance, June 30, $4,508 $13,084 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, January 1, $4,327 $4,562 Other comprehensive income (loss) before reclassifications — 10,050 Amounts reclassified from accumulated other comprehensive income (loss) 181 (1,528) Net other comprehensive income (loss) for the period 181 8,522 Ending balance, June 30, $4,508 $13,084 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $312 $25,086 Competitive business operating revenues Interest rate swaps (48) (48) Miscellaneous - net Total realized gain (loss) on cash flow hedges 264 25,038 Income taxes (56) 5,258 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $208 $30,296 Pension and other postretirement liabilities Amortization of prior-service credit $5,248 $5,682 (a) Amortization of loss (27,534) (27,619) (a) Settlement loss (6,043) — (a) Total amortization (28,329) (21,937) Income taxes 6,231 4,713 Income taxes Total amortization (net of tax) ($22,098) ($17,224) Net unrealized investment gain (loss) Realized gain (loss) $1,196 $6,297 Interest and investment income Income taxes (440) (2,317) Income taxes Total realized investment gain (loss) (net of tax) $756 $3,980 Total reclassifications for the period (net of tax) ($21,134) $17,052 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $119,509 Competitive business operating revenues Interest rate swaps (97) (97) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,582 119,412 Income taxes (8,313) 25,077 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,269 $144,489 Pension and other postretirement liabilities Amortization of prior-service credit $10,496 $9,401 (a) Amortization of loss (62,063) (54,937) (a) Settlement loss (6,043) — (a) Total amortization (57,610) (45,536) Income taxes 12,545 8,762 Income taxes Total amortization (net of tax) ($45,065) ($36,774) Net unrealized investment gain (loss) Realized gain (loss) $224 $9,413 Interest and investment income Income taxes (82) (3,464) Income taxes Total realized investment gain (loss) (net of tax) $142 $5,949 Total reclassifications for the period (net of tax) ($13,654) $113,664 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,230 $1,698 (a) Amortization of loss (626) (419) (a) Settlement loss (1,400) — (a) Total amortization (796) 1,279 Income taxes 208 (334) Income taxes Total amortization (net of tax) (588) 945 Total reclassifications for the period (net of tax) ($588) $945 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $2,460 $2,787 (a) Amortization of loss (1,305) (720) (a) Settlement loss (1,400) — (a) Total amortization (245) 2,067 Income taxes 64 (539) Income taxes Total amortization (net of tax) (181) 1,528 Total reclassifications for the period (net of tax) ($181) $1,528 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Preferred Stock 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 June 30, 2021, no preferred stock has been issued under the new authority.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation and Entergy Louisiana) Common Stock Earnings (Loss) per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings (loss) per share Net income (loss) attributable to Entergy Corporation ($6.0) 200.8 ($0.03) $360.5 200.2 $1.80 Average dilutive effect of: Stock options — — 0.3 — Other equity plans — — 0.4 (0.01) Diluted earnings (loss) per share ($6.0) 200.8 ($0.03) $360.5 200.9 $1.79 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the three months ended June 30, 2021 and approximately 0.5 million for the three months ended June 30, 2020. The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Six Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $328.6 200.7 $1.64 $479.2 200.0 $2.40 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.01) Other equity plans 0.3 — 0.4 — Diluted earnings per share $328.6 201.4 $1.63 $479.2 200.9 $2.39 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the six months ended June 30, 2021 and approximately 0.5 million for the six months ended June 30, 2020. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $0.95 for the three months ended June 30, 2021 and $0.93 for the three months ended June 30, 2020. Dividends declared per common share were $1.90 for the six months ended June 30, 2021 and $1.86 for the six months ended June 30, 2020. 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 six months ended June 30, 2021, Entergy Corporation issued 265,468 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $26.8 million, which includes the gross sales price of $28.2 million received by Entergy Corporation less $1.1 million of general issuance costs and $0.3 million of aggregate compensation to the agents with respect to such sales. In June 2021, Entergy entered into a forward sale agreement for 416,853 shares of common stock. 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 agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares of its common stock to the investment bank in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially $106.87 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million with aggregate compensation to the agents of $0.5 million. Entergy Corporation did not receive any proceeds from such sales of borrowed shares. Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, 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. For the three and six months ended June 30, 2021, shares under the forward sale agreement were not included in the calculation of diluted common shares outstanding because their effect would have been antidilutive. Treasury Stock During the six months ended June 30, 2021, Entergy Corporation issued 443,060 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards. Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2021. Retained Earnings On July 30, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on September 1, 2021, to holders of record as of August 12, 2021. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2021 ($861) ($511,609) $11,963 ($500,507) Other comprehensive income (loss) before reclassifications (14) — 648 634 Amounts reclassified from accumulated other comprehensive income (loss) (208) 22,098 (756) 21,134 Net other comprehensive income (loss) for the period (222) 22,098 (108) 21,768 Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2020 $62,496 ($503,173) $41,690 ($398,987) Other comprehensive income (loss) before reclassifications 4,890 — 22,545 27,435 Amounts reclassified from accumulated other comprehensive income (loss) (30,296) 17,224 (3,980) (17,052) Net other comprehensive income (loss) for the period (25,406) 17,224 18,565 10,383 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,467 — (44,653) (43,186) Amounts reclassified from accumulated other comprehensive income (loss) (31,269) 45,065 (142) 13,654 Net other comprehensive income (loss) for the period (29,802) 45,065 (44,795) (29,532) Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 97,373 34,349 40,258 171,980 Amounts reclassified from accumulated other comprehensive income (loss) (144,489) 36,774 (5,949) (113,664) Net other comprehensive income (loss) for the period (47,116) 71,123 34,309 58,316 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, April 1, $3,920 $14,029 Amounts reclassified from accumulated other comprehensive income (loss) 588 (945) Net other comprehensive income (loss) for the period 588 (945) Ending balance, June 30, $4,508 $13,084 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, January 1, $4,327 $4,562 Other comprehensive income (loss) before reclassifications — 10,050 Amounts reclassified from accumulated other comprehensive income (loss) 181 (1,528) Net other comprehensive income (loss) for the period 181 8,522 Ending balance, June 30, $4,508 $13,084 Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $312 $25,086 Competitive business operating revenues Interest rate swaps (48) (48) Miscellaneous - net Total realized gain (loss) on cash flow hedges 264 25,038 Income taxes (56) 5,258 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $208 $30,296 Pension and other postretirement liabilities Amortization of prior-service credit $5,248 $5,682 (a) Amortization of loss (27,534) (27,619) (a) Settlement loss (6,043) — (a) Total amortization (28,329) (21,937) Income taxes 6,231 4,713 Income taxes Total amortization (net of tax) ($22,098) ($17,224) Net unrealized investment gain (loss) Realized gain (loss) $1,196 $6,297 Interest and investment income Income taxes (440) (2,317) Income taxes Total realized investment gain (loss) (net of tax) $756 $3,980 Total reclassifications for the period (net of tax) ($21,134) $17,052 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $119,509 Competitive business operating revenues Interest rate swaps (97) (97) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,582 119,412 Income taxes (8,313) 25,077 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,269 $144,489 Pension and other postretirement liabilities Amortization of prior-service credit $10,496 $9,401 (a) Amortization of loss (62,063) (54,937) (a) Settlement loss (6,043) — (a) Total amortization (57,610) (45,536) Income taxes 12,545 8,762 Income taxes Total amortization (net of tax) ($45,065) ($36,774) Net unrealized investment gain (loss) Realized gain (loss) $224 $9,413 Interest and investment income Income taxes (82) (3,464) Income taxes Total realized investment gain (loss) (net of tax) $142 $5,949 Total reclassifications for the period (net of tax) ($13,654) $113,664 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,230 $1,698 (a) Amortization of loss (626) (419) (a) Settlement loss (1,400) — (a) Total amortization (796) 1,279 Income taxes 208 (334) Income taxes Total amortization (net of tax) (588) 945 Total reclassifications for the period (net of tax) ($588) $945 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $2,460 $2,787 (a) Amortization of loss (1,305) (720) (a) Settlement loss (1,400) — (a) Total amortization (245) 2,067 Income taxes 64 (539) Income taxes Total amortization (net of tax) (181) 1,528 Total reclassifications for the period (net of tax) ($181) $1,528 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Preferred Stock 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 June 30, 2021, no preferred stock has been issued under the new authority.

Revolving Credit Facilities, Li

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	6 Months Ended
	Jun. 30, 2021
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344 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 Registrant Subsidiaries (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 June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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 0.275% of the undrawn commitment amount. 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 one or more uncommitted standby letter of credit facilities primarily 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 June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 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 limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. 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 were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility. The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K 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 in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs). To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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. The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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 (a) Repaid at maturity 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, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities. Debt Issuances and Retirements (Entergy Corporation) In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes. (Entergy Arkansas) In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes. (Entergy Louisiana) In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes. In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. (Entergy Mississippi) In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes. (Entergy Texas) In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021. (System Energy) In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together with other funds, to refund $83.695 million of outstanding revenue bonds. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2021
Entergy Corporation [Member]
Stock-Based Compensation	STOCK-BASED COMPENSATION (Entergy Corporation)Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K. Awards under Entergy’s plans generally vest over three years. Stock Options Entergy granted options on 508,704 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2021 with a fair value of $12.27 per option. As of June 30, 2021, there were options on 2,844,446 shares of common stock outstanding with a weighted-average exercise price of $90.78. The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2021. The aggregate intrinsic value of the stock options outstanding as of June 30, 2021 was $41.5 million. The following table includes financial information for outstanding stock options for the three months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $1.0 $1.0 Tax benefit recognized in Entergy’s net income $0.2 $0.2 Compensation cost capitalized as part of fixed assets and materials and supplies $0.4 $0.4 The following table includes financial information for outstanding stock options for the six months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $2.0 $2.0 Tax benefit recognized in Entergy’s net income $0.5 $0.5 Compensation cost capitalized as part of fixed assets and materials and supplies $0.8 $0.8 Other Equity Awards In January 2021 the Board approved and Entergy granted 392,382 restricted stock awards and 203,983 long-term incentive awards under the 2019 Omnibus Incentive 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’s common stock on that date. Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date. In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. To emphasize the importance of strong cash generation for the long-term health of its business, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 performance period. Performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure. 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’s common stock on that date. Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-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. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program. The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $9.7 $9.6 Tax benefit recognized in Entergy’s net income $2.5 $2.5 Compensation cost capitalized as part of fixed assets and materials and supplies $4.0 $3.8 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $20.5 $19.0 Tax benefit recognized in Entergy’s net income $5.2 $4.9 Compensation cost capitalized as part of fixed assets and materials and supplies $8.0 $7.2

Retirement And Other Postretire

Retirement And Other Postretirement Benefits	6 Months Ended
	Jun. 30, 2021
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234 Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067 Accounting for Pension and Other Postretirement Benefits In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income. Other Postretirement Benefits In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation. Qualified Pension Settlement Cost In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Entergy Texas Reserve In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million. Employer Contributions Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021. As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans. Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992

Business Segment Information

Business Segment Information	6 Months Ended
	Jun. 30, 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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 June 30, 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 for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. 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.

Risk Management And Fair Values

Risk Management And Fair Values	6 Months Ended
	Jun. 30, 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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu
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 and interest rate swaps. 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 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts. Total planned generation for the remainder of 2021 is 3.4 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 contain provisions that require 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 is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date. As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. 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 it 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 had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 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 June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 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. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 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 June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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 $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales. 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 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. 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. The values for power contract assets or liabilities are 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 are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are 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 include: 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 is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis. The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are 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 would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business. The fair values are 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 are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount is 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 are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, 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 are reviewed and can be adjusted if it is determined that there is a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences are 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 are 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 qu

Decommissioning Trust Funds

Decommissioning Trust Funds	6 Months Ended
	Jun. 30, 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 herein, 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 three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $2,038 $92 $8 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $482 $8 $187 $3 More than 12 months 3 — 2 — Total $485 $8 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 455 672 5 years - 10 years 663 852 10 years - 15 years 335 377 15 years - 20 years 117 144 20 years+ 468 576 Total $2,038 $2,617 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 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 June 30, 2021 was $564 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $472.5 $16.7 $2.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $127.7 $2.7 $29.9 $0.3 More than 12 months 2.0 — — — Total $129.7 $2.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 93.6 113.1 5 years - 10 years 191.6 189.8 10 years - 15 years 121.5 81.4 15 years - 20 years 28.8 28.5 20 years+ 37.0 35.1 Total $472.5 $447.9 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $697.5 $38.4 $1.9 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020. As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $124.4 $1.9 $36.4 $0.5 More than 12 months 0.7 — 0.8 — Total $125.1 $1.9 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 122.7 117.0 5 years - 10 years 188.4 159.4 10 years - 15 years 103.5 101.2 15 years - 20 years 74.3 66.9 20 years+ 208.6 187.7 Total $697.5 $632.2 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $467.8 $19.4 $2.5 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $450.9 million as of June 30, 2021 and $398.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.43%, an average duration of approximately 7.27 years, and an average maturity of approximately 10.68 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $60.6 million and $103.3 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $149.1 $2.5 $28.9 $0.8 More than 12 months 0.1 — — — Total $149.2 $2.5 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 144.0 134.7 5 years - 10 years 147.3 141.5 10 years - 15 years 46.3 31.5 15 years - 20 years 2.8 5.3 20 years+ 127.4 115.8 Total $467.8 $427.7 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $101.6 million and $73.6 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.9 million and $5.4 million, respectively, and gross losses of $0.2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $175.7 million and $165.6 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $3.1 million and $7 million, respectively, and gross losses of $1.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit 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 herein, 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 three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $2,038 $92 $8 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $482 $8 $187 $3 More than 12 months 3 — 2 — Total $485 $8 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 455 672 5 years - 10 years 663 852 10 years - 15 years 335 377 15 years - 20 years 117 144 20 years+ 468 576 Total $2,038 $2,617 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 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 June 30, 2021 was $564 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $472.5 $16.7 $2.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $127.7 $2.7 $29.9 $0.3 More than 12 months 2.0 — — — Total $129.7 $2.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 93.6 113.1 5 years - 10 years 191.6 189.8 10 years - 15 years 121.5 81.4 15 years - 20 years 28.8 28.5 20 years+ 37.0 35.1 Total $472.5 $447.9 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $697.5 $38.4 $1.9 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020. As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $124.4 $1.9 $36.4 $0.5 More than 12 months 0.7 — 0.8 — Total $125.1 $1.9 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 122.7 117.0 5 years - 10 years 188.4 159.4 10 years - 15 years 103.5 101.2 15 years - 20 years 74.3 66.9 20 years+ 208.6 187.7 Total $697.5 $632.2 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $467.8 $19.4 $2.5 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $450.9 million as of June 30, 2021 and $398.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.43%, an average duration of approximately 7.27 years, and an average maturity of approximately 10.68 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $60.6 million and $103.3 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $149.1 $2.5 $28.9 $0.8 More than 12 months 0.1 — — — Total $149.2 $2.5 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 144.0 134.7 5 years - 10 years 147.3 141.5 10 years - 15 years 46.3 31.5 15 years - 20 years 2.8 5.3 20 years+ 127.4 115.8 Total $467.8 $427.7 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $101.6 million and $73.6 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.9 million and $5.4 million, respectively, and gross losses of $0.2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $175.7 million and $165.6 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $3.1 million and $7 million, respectively, and gross losses of $1.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit 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 herein, 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 three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $2,038 $92 $8 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $482 $8 $187 $3 More than 12 months 3 — 2 — Total $485 $8 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 455 672 5 years - 10 years 663 852 10 years - 15 years 335 377 15 years - 20 years 117 144 20 years+ 468 576 Total $2,038 $2,617 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 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 June 30, 2021 was $564 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $472.5 $16.7 $2.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $127.7 $2.7 $29.9 $0.3 More than 12 months 2.0 — — — Total $129.7 $2.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 93.6 113.1 5 years - 10 years 191.6 189.8 10 years - 15 years 121.5 81.4 15 years - 20 years 28.8 28.5 20 years+ 37.0 35.1 Total $472.5 $447.9 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $697.5 $38.4 $1.9 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020. As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $124.4 $1.9 $36.4 $0.5 More than 12 months 0.7 — 0.8 — Total $125.1 $1.9 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 122.7 117.0 5 years - 10 years 188.4 159.4 10 years - 15 years 103.5 101.2 15 years - 20 years 74.3 66.9 20 years+ 208.6 187.7 Total $697.5 $632.2 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $467.8 $19.4 $2.5 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $450.9 million as of June 30, 2021 and $398.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.43%, an average duration of approximately 7.27 years, and an average maturity of approximately 10.68 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $60.6 million and $103.3 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $149.1 $2.5 $28.9 $0.8 More than 12 months 0.1 — — — Total $149.2 $2.5 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 144.0 134.7 5 years - 10 years 147.3 141.5 10 years - 15 years 46.3 31.5 15 years - 20 years 2.8 5.3 20 years+ 127.4 115.8 Total $467.8 $427.7 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $101.6 million and $73.6 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.9 million and $5.4 million, respectively, and gross losses of $0.2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $175.7 million and $165.6 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $3.1 million and $7 million, respectively, and gross losses of $1.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit 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 herein, 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 three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $2,038 $92 $8 2020 Debt Securities $2,617 $197 $3 The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $482 $8 $187 $3 More than 12 months 3 — 2 — Total $485 $8 $189 $3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 455 672 5 years - 10 years 663 852 10 years - 15 years 335 377 15 years - 20 years 117 144 20 years+ 468 576 Total $2,038 $2,617 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 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 June 30, 2021 was $564 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $472.5 $16.7 $2.7 2020 Debt Securities $447.9 $27.7 $0.3 The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $127.7 $2.7 $29.9 $0.3 More than 12 months 2.0 — — — Total $129.7 $2.7 $29.9 $0.3 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 93.6 113.1 5 years - 10 years 191.6 189.8 10 years - 15 years 121.5 81.4 15 years - 20 years 28.8 28.5 20 years+ 37.0 35.1 Total $472.5 $447.9 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $697.5 $38.4 $1.9 2020 Debt Securities $632.2 $51.3 $0.5 The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020. As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $124.4 $1.9 $36.4 $0.5 More than 12 months 0.7 — 0.8 — Total $125.1 $1.9 $37.2 $0.5 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 122.7 117.0 5 years - 10 years 188.4 159.4 10 years - 15 years 103.5 101.2 15 years - 20 years 74.3 66.9 20 years+ 208.6 187.7 Total $697.5 $632.2 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 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 June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $467.8 $19.4 $2.5 2020 Debt Securities $427.7 $30.0 $0.8 The amortized cost of available-for-sale debt securities was $450.9 million as of June 30, 2021 and $398.4 million as of December 31, 2020. As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.43%, an average duration of approximately 7.27 years, and an average maturity of approximately 10.68 years. The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $60.6 million and $103.3 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $149.1 $2.5 $28.9 $0.8 More than 12 months 0.1 — — — Total $149.2 $2.5 $28.9 $0.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 144.0 134.7 5 years - 10 years 147.3 141.5 10 years - 15 years 46.3 31.5 15 years - 20 years 2.8 5.3 20 years+ 127.4 115.8 Total $467.8 $427.7 During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $101.6 million and $73.6 million, respectively. During the three months ended June 30, 2021 and 2020, gross gains of $1.9 million and $5.4 million, respectively, and gross losses of $0.2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $175.7 million and $165.6 million, respectively. During the six months ended June 30, 2021 and 2020, gross gains of $3.1 million and $7 million, respectively, and gross losses of $1.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Allowance for expected credit losses

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2021
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “ Income Tax Audits ” and “ Other Tax Matters ” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $— Valuation Allowance

Property, Plant, And Equipment

Property, Plant, And Equipment	6 Months Ended
	Jun. 30, 2021
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
Entergy Arkansas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
Entergy Louisiana [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
Entergy Mississippi [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
Entergy New Orleans [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
Entergy Texas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.
System Energy [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy. Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $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.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2021
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
Entergy Arkansas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
Entergy Louisiana [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
Entergy Mississippi [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
Entergy New Orleans [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
Entergy Texas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.
System Energy [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities. See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.

Revenue Recognition

Revenue Recognition	6 Months Ended
	Jun. 30, 2021
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Arkansas [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Louisiana [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Mississippi [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy New Orleans [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Texas [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
System Energy [Member]
Revenue Recognition	REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Operating Revenues See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition. Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967 The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530 (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 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 increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8

Business Combinations

Business Combinations	6 Months Ended
	Jun. 30, 2021
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	ACQUISITIONS AND DISPOSITIONS (Entergy Corporation and Entergy Texas) Acquisitions 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 $67.9 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $36.7 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.
Entergy Texas [Member]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	ACQUISITIONS AND DISPOSITIONS (Entergy Corporation and Entergy Texas) Acquisitions 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 $67.9 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $36.7 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.

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2021
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Three Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings (loss) per share Net income (loss) attributable to Entergy Corporation ($6.0) 200.8 ($0.03) $360.5 200.2 $1.80 Average dilutive effect of: Stock options — — 0.3 — Other equity plans — — 0.4 (0.01) Diluted earnings (loss) per share ($6.0) 200.8 ($0.03) $360.5 200.9 $1.79 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the three months ended June 30, 2021 and approximately 0.5 million for the three months ended June 30, 2020. The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements: For the Six Months Ended June 30, 2021 2020 (In Millions, Except Per Share Data) Income Shares $/share Income Shares $/share Basic earnings per share Net income attributable to Entergy Corporation $328.6 200.7 $1.64 $479.2 200.0 $2.40 Average dilutive effect of: Stock options 0.4 (0.01) 0.5 (0.01) Other equity plans 0.3 — 0.4 — Diluted earnings per share $328.6 201.4 $1.63 $479.2 200.9 $2.39 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the six months ended June 30, 2021 and approximately 0.5 million for the six months ended June 30, 2020.
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2021 ($861) ($511,609) $11,963 ($500,507) Other comprehensive income (loss) before reclassifications (14) — 648 634 Amounts reclassified from accumulated other comprehensive income (loss) (208) 22,098 (756) 21,134 Net other comprehensive income (loss) for the period (222) 22,098 (108) 21,768 Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, April 1, 2020 $62,496 ($503,173) $41,690 ($398,987) Other comprehensive income (loss) before reclassifications 4,890 — 22,545 27,435 Amounts reclassified from accumulated other comprehensive income (loss) (30,296) 17,224 (3,980) (17,052) Net other comprehensive income (loss) for the period (25,406) 17,224 18,565 10,383 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2021 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2021 $28,719 ($534,576) $56,650 ($449,207) Other comprehensive income (loss) before reclassifications 1,467 — (44,653) (43,186) Amounts reclassified from accumulated other comprehensive income (loss) (31,269) 45,065 (142) 13,654 Net other comprehensive income (loss) for the period (29,802) 45,065 (44,795) (29,532) Ending balance, June 30, 2021 ($1,083) ($489,511) $11,855 ($478,739) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2020 by component: Cash flow Pension Net Total (In Thousands) Beginning balance, January 1, 2020 $84,206 ($557,072) $25,946 ($446,920) Other comprehensive income (loss) before reclassifications 97,373 34,349 40,258 171,980 Amounts reclassified from accumulated other comprehensive income (loss) (144,489) 36,774 (5,949) (113,664) Net other comprehensive income (loss) for the period (47,116) 71,123 34,309 58,316 Ending balance, June 30, 2020 $37,090 ($485,949) $60,255 ($388,604)
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $312 $25,086 Competitive business operating revenues Interest rate swaps (48) (48) Miscellaneous - net Total realized gain (loss) on cash flow hedges 264 25,038 Income taxes (56) 5,258 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $208 $30,296 Pension and other postretirement liabilities Amortization of prior-service credit $5,248 $5,682 (a) Amortization of loss (27,534) (27,619) (a) Settlement loss (6,043) — (a) Total amortization (28,329) (21,937) Income taxes 6,231 4,713 Income taxes Total amortization (net of tax) ($22,098) ($17,224) Net unrealized investment gain (loss) Realized gain (loss) $1,196 $6,297 Interest and investment income Income taxes (440) (2,317) Income taxes Total realized investment gain (loss) (net of tax) $756 $3,980 Total reclassifications for the period (net of tax) ($21,134) $17,052 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Cash flow hedges net unrealized gain (loss) Power contracts $39,679 $119,509 Competitive business operating revenues Interest rate swaps (97) (97) Miscellaneous - net Total realized gain (loss) on cash flow hedges 39,582 119,412 Income taxes (8,313) 25,077 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $31,269 $144,489 Pension and other postretirement liabilities Amortization of prior-service credit $10,496 $9,401 (a) Amortization of loss (62,063) (54,937) (a) Settlement loss (6,043) — (a) Total amortization (57,610) (45,536) Income taxes 12,545 8,762 Income taxes Total amortization (net of tax) ($45,065) ($36,774) Net unrealized investment gain (loss) Realized gain (loss) $224 $9,413 Interest and investment income Income taxes (82) (3,464) Income taxes Total realized investment gain (loss) (net of tax) $142 $5,949 Total reclassifications for the period (net of tax) ($13,654) $113,664 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, April 1, $3,920 $14,029 Amounts reclassified from accumulated other comprehensive income (loss) 588 (945) Net other comprehensive income (loss) for the period 588 (945) Ending balance, June 30, $4,508 $13,084 The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2021 and 2020: Pension and Other 2021 2020 (In Thousands) Beginning balance, January 1, $4,327 $4,562 Other comprehensive income (loss) before reclassifications — 10,050 Amounts reclassified from accumulated other comprehensive income (loss) 181 (1,528) Net other comprehensive income (loss) for the period 181 8,522 Ending balance, June 30, $4,508 $13,084
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $1,230 $1,698 (a) Amortization of loss (626) (419) (a) Settlement loss (1,400) — (a) Total amortization (796) 1,279 Income taxes 208 (334) Income taxes Total amortization (net of tax) (588) 945 Total reclassifications for the period (net of tax) ($588) $945 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the six months ended June 30, 2021 and 2020 were as follows: Amounts reclassified Income Statement Location 2021 2020 (In Thousands) Pension and other postretirement liabilities Amortization of prior-service credit $2,460 $2,787 (a) Amortization of loss (1,305) (720) (a) Settlement loss (1,400) — (a) Total amortization (245) 2,067 Income taxes 64 (539) Income taxes Total amortization (net of tax) (181) 1,528 Total reclassifications for the period (net of tax) ($181) $1,528 (a) These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Revolving Credit Facilities, _2

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2021. Capacity Borrowings Letters Capacity (In Millions) $3,500 $150 $6 $3,344
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows: Company Expiration Amount of Interest Rate (a) Amount Drawn Letters of Credit 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) 1.23% $— $— Entergy Mississippi April 2022 $37.5 million (d) 1.60% $— $— Entergy Mississippi April 2022 $35 million (d) 1.60% $— $— Entergy Mississippi April 2022 $10 million (d) 1.60% $— $— Entergy New Orleans June 2024 $25 million (c) 1.58% $— $— Entergy Texas June 2026 $150 million (c) 1.60% $— $1.3 million (a) The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the 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.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021: Company Amount of Letter of Credit Fee MISO Letters of Credit Entergy Arkansas $25 million 0.78% $2.5 million Entergy Louisiana $125 million 0.78% $7.8 million Entergy Mississippi $65 million 0.78% $2 million Entergy New Orleans $15 million 1.00% $1 million Entergy Texas $50 million 0.70% $18.2 million (a) As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights. (b) As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 System Energy $200 $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries: Authorized Borrowings (In Millions) Entergy Arkansas $250 $— Entergy Louisiana $450 $— Entergy Mississippi $175 $17 Entergy New Orleans $150 $38 Entergy Texas $200 $63 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 have commercial paper programs in place. Following is a summary as of June 30, 2021: Company Expiration Amount Weighted Amount (Dollars in Millions) Entergy Arkansas VIE June 2024 $80 1.26% $— Entergy Louisiana River Bend VIE June 2024 $105 1.22% $64.6 Entergy Louisiana Waterford VIE June 2024 $105 1.22% $62.1 System Energy VIE June 2024 $120 1.22% $45.7 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, 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 were included in debt on the respective balance sheets as of June 30, 2021 as follows: Company Description Amount Entergy Arkansas VIE 3.65% Series L due July 2021 (a) $90 million 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
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows: Book Value Fair Value (In Thousands) Entergy $24,497,290 $26,221,663 Entergy Arkansas $4,043,714 $4,327,356 Entergy Louisiana $9,836,133 $10,746,564 Entergy Mississippi $1,981,674 $2,166,517 Entergy New Orleans $636,870 $584,209 Entergy Texas $2,323,879 $2,496,970 System Energy $750,939 $771,477 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows: Book Value Fair Value (In Thousands) Entergy $22,369,776 $24,813,818 Entergy Arkansas $3,967,507 $4,355,632 Entergy Louisiana $9,027,451 $10,258,294 Entergy Mississippi $1,780,577 $2,021,432 Entergy New Orleans $642,233 $620,634 Entergy Texas $2,493,708 $2,765,193 System Energy $805,274 $840,540 (a) Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables) - Entergy Corporation [Member]	6 Months Ended
	Jun. 30, 2021
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Financial Information For Stock Options	The following table includes financial information for outstanding stock options for the three months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $1.0 $1.0 Tax benefit recognized in Entergy’s net income $0.2 $0.2 Compensation cost capitalized as part of fixed assets and materials and supplies $0.4 $0.4 The following table includes financial information for outstanding stock options for the six months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $2.0 $2.0 Tax benefit recognized in Entergy’s net income $0.5 $0.5 Compensation cost capitalized as part of fixed assets and materials and supplies $0.8 $0.8
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $9.7 $9.6 Tax benefit recognized in Entergy’s net income $2.5 $2.5 Compensation cost capitalized as part of fixed assets and materials and supplies $4.0 $3.8 The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2021 and 2020: 2021 2020 (In Millions) Compensation expense included in Entergy’s net income $20.5 $19.0 Tax benefit recognized in Entergy’s net income $5.2 $4.9 Compensation cost capitalized as part of fixed assets and materials and supplies $8.0 $7.2

Retirement And Other Postreti_2

Retirement And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2021
Defined Benefit Plan Disclosure [Line Items]
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) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $42,951 $40,379 Interest cost on projected benefit obligation 47,382 60,799 Expected return on assets (106,039) (103,565) Amortization of net loss 92,799 87,259 Settlement charges 111,549 — Net pension costs $188,642 $84,872 Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $88,191 $80,758 Interest cost on projected benefit obligation 93,480 121,598 Expected return on assets (211,753) (207,130) Amortization of net loss 197,190 174,518 Settlement charges 111,549 — Net pension costs $278,657 $169,744
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $6,645 $6,231 Interest cost on accumulated postretirement benefit obligation (APBO) 5,320 6,888 Expected return on assets (10,805) (10,182) Amortization of prior service credit (8,267) (8,985) Amortization of net loss 713 1,005 Net other postretirement benefit income ($6,394) ($5,043) Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components: 2021 2020 (In Thousands) Service cost - benefits earned during the period $13,290 $12,032 Interest cost on accumulated postretirement benefit obligation (APBO) 10,640 14,820 Expected return on assets (21,610) (20,510) Amortization of prior service credit (16,534) (14,907) Amortization of net loss 1,426 1,473 Net other postretirement benefit income ($12,788) ($7,092)
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Arkansas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
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) for the second quarters of 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,288 ($40) $5,248 Amortization of net loss (26,443) (496) (595) (27,534) Settlement loss (6,043) — — (6,043) ($32,486) $4,792 ($635) ($28,329) Entergy Louisiana Amortization of prior service credit $— $1,230 $— $1,230 Amortization of net gain (loss) (716) 91 (1) (626) Settlement loss (1,400) — — ($1,400) ($2,116) $1,321 ($1) ($796) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $5,739 ($57) $5,682 Amortization of net loss (26,461) (327) (831) (27,619) ($26,461) $5,412 ($888) ($21,937) Entergy Louisiana Amortization of prior service credit $— $1,698 $— $1,698 Amortization of net gain (loss) (499) 81 (1) (419) ($499) $1,779 ($1) $1,279 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020: 2021 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $10,576 ($80) $10,496 Amortization of net loss (59,883) (990) (1,190) (62,063) Settlement loss (6,043) — — (6,043) ($65,926) $9,586 ($1,270) ($57,610) Entergy Louisiana Amortization of prior service credit $— $2,460 $— $2,460 Amortization of net gain (loss) (1,484) 182 (3) (1,305) Settlement loss (1,400) — — (1,400) ($2,884) $2,642 ($3) ($245) 2020 Qualified Other Non-Qualified Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $9,516 ($115) $9,401 Amortization of net loss (52,923) (352) (1,662) (54,937) ($52,923) $9,164 ($1,777) ($45,536) Entergy Louisiana Amortization of prior service credit $— $2,787 $— $2,787 Amortization of net gain (loss) (998) 280 (2) (720) ($998) $3,067 ($2) $2,067
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Louisiana [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234
Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Mississippi [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234
Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy New Orleans [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234
Entergy Texas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
Entergy Texas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)
Entergy Texas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $90 $44 $96 $8 $115 2020 $83 $37 $90 $8 $117 The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020: Entergy Entergy Entergy Entergy Entergy (In Thousands) 2021 $180 $88 $192 $16 $230 2020 $166 $74 $180 $16 $234
System Energy [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $7,255 $9,759 $2,304 $774 $1,757 $2,253 Interest cost on projected benefit obligation 8,752 9,864 2,571 1,079 2,052 2,236 Expected return on assets (19,640) (22,516) (5,600) (2,641) (5,272) (4,804) Amortization of net loss 18,250 17,890 5,309 2,069 3,415 4,933 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $39,003 $49,989 $12,346 $4,866 $8,578 $9,256 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $6,566 $8,794 $2,023 $663 $1,546 $1,965 Interest cost on projected benefit obligation 11,433 12,841 3,340 1,456 2,782 2,814 Expected return on assets (19,622) (22,402) (5,757) (2,627) (5,486) (4,663) Amortization of net loss 16,897 16,627 4,748 2,005 3,265 4,279 Net pension cost $15,274 $15,860 $4,354 $1,497 $2,107 $4,395 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $14,674 $19,803 $4,668 $1,569 $3,557 $4,566 Interest cost on projected benefit obligation 17,092 19,425 5,034 2,108 4,002 4,378 Expected return on assets (39,311) (45,055) (11,186) (5,263) (10,510) (9,583) Amortization of net loss 37,552 37,093 10,976 4,340 7,126 10,258 Settlement charges 24,386 34,992 7,762 3,585 6,626 4,638 Net pension cost $54,393 $66,258 $17,254 $6,339 $10,801 $14,257 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $13,132 $17,588 $4,046 $1,326 $3,092 $3,930 Interest cost on projected benefit obligation 22,866 25,682 6,680 2,912 5,564 5,628 Expected return on assets (39,244) (44,804) (11,514) (5,254) (10,972) (9,326) Amortization of net loss 33,794 33,254 9,496 4,010 6,530 8,558 Net pension cost $30,548 $31,720 $8,708 $2,994 $4,214 $8,790
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021: Entergy Entergy Entergy Entergy Entergy System (In Thousands) Expected 2021 pension contributions $66,649 $59,882 $13,715 $5,395 $6,955 $18,663 Pension contributions made through June 2021 $36,457 $39,400 $7,771 $3,551 $4,275 $10,671 Remaining estimated pension contributions to be made in 2021 $30,192 $20,482 $5,944 $1,844 $2,680 $7,992
System Energy [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,034 $1,544 $362 $109 $346 $335 Interest cost on APBO 932 1,130 278 130 317 220 Expected return on assets (4,505) — (1,384) (1,438) (2,548) (789) Amortization of prior service credit (280) (1,230) (444) (229) (936) (109) Amortization of net (gain) loss 49 (91) 19 (178) 100 15 Net other postretirement benefit cost (income) ($2,770) $1,353 ($1,169) ($1,606) ($2,721) ($328) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $933 $1,524 $372 $114 $306 $321 Interest cost on APBO 1,164 1,497 372 186 477 276 Expected return on assets (4,260) — (1,287) (1,344) (2,403) (735) Amortization of prior service credit (396) (1,695) (444) (228) (939) (282) Amortization of net (gain) loss 162 (81) 48 9 231 33 Net other postretirement benefit cost (income) ($2,397) $1,245 ($939) ($1,263) ($2,328) ($387) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components: 2021 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $2,068 $3,088 $724 $218 $692 $670 Interest cost on APBO 1,864 2,260 556 260 634 440 Expected return on assets (9,010) — (2,768) (2,876) (5,096) (1,578) Amortization of prior service credit (560) (2,460) (888) (458) (1,872) (218) Amortization of net (gain) loss 98 (182) 38 (356) 200 30 Net other postretirement benefit cost (income) ($5,540) $2,706 ($2,338) ($3,212) ($5,442) ($656) 2020 Entergy Entergy Entergy Entergy Entergy System (In Thousands) Service cost - benefits earned during the period $1,761 $2,947 $723 $219 $609 $615 Interest cost on APBO 2,381 3,220 794 413 1,059 583 Expected return on assets (8,586) — (2,594) (2,699) (4,838) (1,483) Amortization of prior service credit (1,057) (2,784) (765) (304) (1,489) (501) Amortization of net (gain) loss 217 (280) 77 (29) 443 53 Net other postretirement benefit cost (income) ($5,284) $3,103 ($1,765) ($2,400) ($4,216) ($733)

Business Segment Information (T

Business Segment Information (Tables) - Entergy Corporation [Member]	6 Months Ended
	Jun. 30, 2021
Segment Financial Information	Entergy’s segment financial information for the second quarters of 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Entergy (In Thousands) 2021 Operating revenues $2,673,385 $148,656 $31 ($2) $2,822,070 Income taxes $71,360 ($71,696) ($18,080) $— ($18,416) Consolidated net income (loss) $329,936 ($274,648) ($24,784) ($31,898) ($1,394) 2020 Operating revenues $2,213,061 $199,709 $18 $— $2,412,788 Income taxes $73,710 $24,467 ($9,062) $— $89,115 Consolidated net income (loss) $348,902 $85,178 ($37,069) ($31,898) $365,113 Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows: Utility Entergy All Other Eliminations Consolidated (In Thousands) 2021 Operating revenues $5,270,000 $396,874 $54 ($21) $5,666,907 Income taxes $131,094 ($56,135) ($27,433) $— $47,526 Consolidated net income (loss) $690,535 ($236,525) ($52,464) ($63,796) $337,750 Total assets as of June 30, 2021 $56,240,370 $1,209,209 $496,043 ($1,996,339) $55,949,283 2020 Operating revenues $4,307,690 $532,258 $29 ($10) $4,839,967 Income taxes $20,761 ($6,073) $3,233 $— $17,921 Consolidated net income (loss) $672,751 ($25,251) ($95,298) ($63,796) $488,406 Total assets as of December 31, 2020 $55,940,153 $3,800,378 $552,632 ($2,053,951) $58,239,212 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.” Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment.
Restructuring and Related Costs [Table Text Block]	Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of April 1, $157 $14 $171 $150 $14 $164 Restructuring costs accrued (6) 1 (5) 17 — 17 Cash paid out 118 15 133 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167 In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following: 2021 2020 Employee retention and severance Contracted economic development costs Total Employee retention and severance Contracted economic development costs Total (In Millions) Balance as of January 1, $145 $14 $159 $129 $14 $143 Restructuring costs accrued 7 1 8 38 — 38 Cash paid out 119 15 134 14 — 14 Balance as of June 30, $33 $— $33 $153 $14 $167

Risk Management And Fair Valu_2

Risk Management And Fair Values (Tables)	6 Months Ended
	Jun. 30, 2021
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 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) $15 $— $15 Utility Financial transmission rights Prepayments and other $16 ($1) $15 Utility and Entergy Wholesale Commodities 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 Assets: 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
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $— Competitive businesses operating revenues $— 2020 Electricity swaps and options ($7) Competitive businesses operating revenues $25 (a) Before taxes of $5 million for the three months ended June 30, 2020 The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Amount of gain (loss) Income Statement location Amount of gain (In Millions) (In Millions) 2021 Electricity swaps and options $2 Competitive businesses operating revenues $40 2020 Electricity swaps and options $60 Competitive businesses operating revenues $120 (a) Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, 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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) $18 Financial transmission rights Purchased power expense (b) $16 Electricity swaps and options (c) Competitive business operating revenues $— 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($3) Financial transmission rights Purchased power expense (b) $15 Electricity swaps and options (c) Competitive business operating revenues ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Amount of gain (loss) (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale (a) $25 Financial transmission rights Purchased power expense (b) $144 Electricity swaps and options (c) Competitive business operating revenues ($2) 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights Purchased power expense (b) $28 Electricity swaps and options (c) Competitive business operating revenues ($2) (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options.
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 were accounted for at fair value on a recurring basis as of June 30, 2021 and December 31, 2020. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2021 Level 1 Level 2 Level 3 Total (In Millions) Assets: Temporary cash investments $530 $— $— $530 Decommissioning trust funds (a): Equity securities 53 — — 53 Debt securities (b) 686 1,352 — 2,038 Common trusts (c) 3,148 Securitization recovery trust account 33 — — 33 Escrow accounts 88 — — 88 Gas hedge contracts 15 — — 15 Financial transmission rights — — 15 15 $1,405 $1,352 $15 $5,920 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 (b) 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 herein for additional information on the investment portfolios. (b) The decommissioning trust funds fair values presented herein do not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.2 million as of June 30, 2021 and $0.1 million as of December 31, 2020 on debt securities. See Note 9 to the financial statements herein 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 three months ended June 30, 2021 and 2020: 2021 2020 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of April 1, $— $4 $85 $4 Total gains (losses) for the period (a) Included in earnings — — 16 — Included in other comprehensive income — — (7) — Included as a regulatory liability/asset — 15 — 10 Issuances of financial transmission rights — 12 — 23 Settlements — (16) (45) (15) Balance as of June 30, $— $15 $49 $22 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $3 million for the three months ended June 30, 2020. 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 six months ended June 30, 2021 and 2020: 2021 2020 Power Contracts Financial transmission rights Power Contracts Financial transmission rights (In Millions) Balance as of January 1, $38 $9 $118 $10 Total gains (losses) for the period (a) Included in earnings (2) 3 (2) — Included in other comprehensive income 2 — 60 — Included as a regulatory liability/asset — 135 — 17 Issuances of financial transmission rights — 12 — 23 Settlements (38) (144) (127) (28) Balance as of June 30, $— $15 $49 $22
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 June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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.
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 $16.2 $— $— $16.2 Decommissioning trust funds (a): Equity securities 12.7 — — 12.7 Debt securities 99.2 373.3 — 472.5 Common trusts (b) 891.5 Financial transmission rights — — 3.8 3.8 $128.1 $373.3 $3.8 $1,396.7 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 (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.4 $1.2 $0.3 $0.1 $0.5 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 3.0 5.4 0.8 0.9 5.4 Settlements (3.4) (5.9) (0.7) (0.8) (4.8) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 three months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $1.9 $0.3 $— $0.3 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 3.3 2.8 (1.0) 0.1 5.2 Settlements (4.8) (5.4) 0.4 (0.2) (5.3) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6 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 six months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 27.8 14.7 7.7 2.1 82.2 Settlements (29.5) (18.2) (7.9) (2.0) (82.7) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 six months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 5.7 5.5 (1.6) 0.2 6.9 Settlements (9.4) (10.7) 0.5 (0.6) (7.6) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6
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 June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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.
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 $206.6 $— $— $206.6 Decommissioning trust funds (a): Equity securities 19.6 — — 19.6 Debt securities 213.2 484.3 — 697.5 Common trusts (b) 1,268.4 Securitization recovery trust account 3.7 — — 3.7 Gas hedge contracts 5.0 0.4 — 5.4 Financial transmission rights — — 4.8 4.8 $448.1 $484.7 $4.8 $2,206.0 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 (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.4 $1.2 $0.3 $0.1 $0.5 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 3.0 5.4 0.8 0.9 5.4 Settlements (3.4) (5.9) (0.7) (0.8) (4.8) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 three months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $1.9 $0.3 $— $0.3 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 3.3 2.8 (1.0) 0.1 5.2 Settlements (4.8) (5.4) 0.4 (0.2) (5.3) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6 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 six months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 27.8 14.7 7.7 2.1 82.2 Settlements (29.5) (18.2) (7.9) (2.0) (82.7) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 six months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 5.7 5.5 (1.6) 0.2 6.9 Settlements (9.4) (10.7) 0.5 (0.6) (7.6) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6
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 June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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.
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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: Escrow accounts $48.9 $— $— $48.9 Gas hedge contracts 9.6 — — 9.6 Financial transmission rights — — 2.0 2.0 $58.5 $— $2.0 $60.5 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 (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.4 $1.2 $0.3 $0.1 $0.5 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 3.0 5.4 0.8 0.9 5.4 Settlements (3.4) (5.9) (0.7) (0.8) (4.8) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 three months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $1.9 $0.3 $— $0.3 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 3.3 2.8 (1.0) 0.1 5.2 Settlements (4.8) (5.4) 0.4 (0.2) (5.3) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6 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 six months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 27.8 14.7 7.7 2.1 82.2 Settlements (29.5) (18.2) (7.9) (2.0) (82.7) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 six months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 5.7 5.5 (1.6) 0.2 6.9 Settlements (9.4) (10.7) 0.5 (0.6) (7.6) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6
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 June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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.
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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: Securitization recovery trust account $2.7 $— $— $2.7 Escrow accounts 38.8 — — 38.8 Gas hedge contracts 0.1 — — 0.1 Financial transmission rights — — 0.6 0.6 $41.6 $— $0.6 $42.2 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 (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.4 $1.2 $0.3 $0.1 $0.5 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 3.0 5.4 0.8 0.9 5.4 Settlements (3.4) (5.9) (0.7) (0.8) (4.8) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 three months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $1.9 $0.3 $— $0.3 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 3.3 2.8 (1.0) 0.1 5.2 Settlements (4.8) (5.4) 0.4 (0.2) (5.3) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6 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 six months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 27.8 14.7 7.7 2.1 82.2 Settlements (29.5) (18.2) (7.9) (2.0) (82.7) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 six months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 5.7 5.5 (1.6) 0.2 6.9 Settlements (9.4) (10.7) 0.5 (0.6) (7.6) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6
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 June 30, 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) Registrant (In Millions) Assets: Natural gas swaps and options Prepayments and other $5.0 $— $5.0 Entergy Louisiana Natural gas swaps and options Other deferred debits and other assets (non-current portion) $0.4 $— $0.4 Entergy Louisiana Natural gas swaps Prepayments and other $9.6 $— $9.6 Entergy Mississippi Natural gas swaps Prepayments and other $0.1 $— $0.1 Entergy New Orleans Financial transmission rights Prepayments and other $4.1 ($0.3) $3.8 Entergy Arkansas Financial transmission rights Prepayments and other $4.9 ($0.1) $4.8 Entergy Louisiana Financial transmission rights Prepayments and other $2.0 $— $2.0 Entergy Mississippi Financial transmission rights Prepayments and other $0.6 $— $0.6 Entergy New Orleans Financial transmission rights Prepayments and other $3.8 $— $3.8 Entergy Texas The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows: Instrument Balance Sheet Location Gross Fair Value (a) Offsetting Position (b) Net Fair Value (c) (d) Registrant (In Millions) 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 June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 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.
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 three months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $4.9 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $13.2 (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $0.1 (a) Entergy New Orleans Financial transmission rights Purchased power expense $3.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.9 (b) Entergy Louisiana Financial transmission rights Purchased power expense $0.7 (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.8 (b) Entergy New Orleans Financial transmission rights Purchased power expense $4.8 (b) Entergy Texas 2020 Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($2.5) (a) Entergy Mississippi Financial transmission rights Purchased power expense $4.8 (b) Entergy Arkansas Financial transmission rights Purchased power expense $5.4 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.4) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.2 (b) Entergy New Orleans Financial transmission rights Purchased power expense $5.3 (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows: Instrument Income Statement Location Amount of gain Registrant (In Millions) 2021 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale $6.7 (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale $18.3 (a) Entergy Mississippi Financial transmission rights Purchased power expense $29.5 (b) Entergy Arkansas Financial transmission rights Purchased power expense $18.2 (b) Entergy Louisiana Financial transmission rights Purchased power expense $7.9 (b) Entergy Mississippi Financial transmission rights Purchased power expense $2.0 (b) Entergy New Orleans Financial transmission rights Purchased power expense $82.7 (b) Entergy Texas 2020 Natural gas swaps and options Fuel, fuel-related expenses, and gas purchased for resale ($1.3) (a) Entergy Louisiana Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($7.7) (a) Entergy Mississippi Natural gas swaps Fuel, fuel-related expenses, and gas purchased for resale ($0.4) (a) Entergy New Orleans Financial transmission rights Purchased power expense $9.4 (b) Entergy Arkansas Financial transmission rights Purchased power expense $10.7 (b) Entergy Louisiana Financial transmission rights Purchased power expense ($0.5) (b) Entergy Mississippi Financial transmission rights Purchased power expense $0.6 (b) Entergy New Orleans Financial transmission rights Purchased power expense $7.6 (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 $26.3 $— $— $26.3 Financial transmission rights — — 3.8 3.8 $26.3 $— $3.8 $30.1 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 (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.4 $1.2 $0.3 $0.1 $0.5 Issuances of financial transmission rights 2.8 4.1 1.7 0.4 2.7 Gains (losses) included as a regulatory liability/asset 3.0 5.4 0.8 0.9 5.4 Settlements (3.4) (5.9) (0.7) (0.8) (4.8) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 three months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of April 1, $1.1 $1.9 $0.3 $— $0.3 Issuances of financial transmission rights 6.5 13.2 1.4 (0.1) 2.4 Gains (losses) included as a regulatory liability/asset 3.3 2.8 (1.0) 0.1 5.2 Settlements (4.8) (5.4) 0.4 (0.2) (5.3) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6 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 six months ended June 30, 2021. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 27.8 14.7 7.7 2.1 82.2 Settlements (29.5) (18.2) (7.9) (2.0) (82.7) Balance as of June 30, $3.8 $4.8 $2.1 $0.6 $3.8 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 six months ended June 30, 2020. Entergy Entergy Entergy Entergy Entergy (In Millions) Balance as of January 1, $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 5.7 5.5 (1.6) 0.2 6.9 Settlements (9.4) (10.7) 0.5 (0.6) (7.6) Balance as of June 30, $6.1 $12.5 $1.1 ($0.2) $2.6
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 $119.1 $— $— $119.1 Decommissioning trust funds (a): Equity securities 6.0 — — 6.0 Debt Securities 207.3 260.5 — 467.8 Common trusts (b) 838.7 $332.4 $260.5 $— $1,431.6 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)	6 Months Ended
	Jun. 30, 2021
Securities Held	The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $2,038 $92 $8 2020 Debt Securities $2,617 $197 $3
Available For Sale Securities Continuous 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 June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $482 $8 $187 $3 More than 12 months 3 — 2 — Total $485 $8 $189 $3
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($4) 1 year - 5 years 455 672 5 years - 10 years 663 852 10 years - 15 years 335 377 15 years - 20 years 117 144 20 years+ 468 576 Total $2,038 $2,617
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $472.5 $16.7 $2.7 2020 Debt Securities $447.9 $27.7 $0.3
Available For Sale Securities Continuous 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 June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $127.7 $2.7 $29.9 $0.3 More than 12 months 2.0 — — — Total $129.7 $2.7 $29.9 $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 June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 93.6 113.1 5 years - 10 years 191.6 189.8 10 years - 15 years 121.5 81.4 15 years - 20 years 28.8 28.5 20 years+ 37.0 35.1 Total $472.5 $447.9
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $697.5 $38.4 $1.9 2020 Debt Securities $632.2 $51.3 $0.5
Available For Sale Securities Continuous 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 June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $124.4 $1.9 $36.4 $0.5 More than 12 months 0.7 — 0.8 — Total $125.1 $1.9 $37.2 $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 June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— $— 1 year - 5 years 122.7 117.0 5 years - 10 years 188.4 159.4 10 years - 15 years 103.5 101.2 15 years - 20 years 74.3 66.9 20 years+ 208.6 187.7 Total $697.5 $632.2
System Energy [Member]
Securities Held	The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows: Fair Total Total (In Millions) 2021 Debt Securities $467.8 $19.4 $2.5 2020 Debt Securities $427.7 $30.0 $0.8
Available For Sale Securities Continuous 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 June 30, 2021 and December 31, 2020: June 30, 2021 December 31, 2020 Fair Gross Fair Gross (In Millions) Less than 12 months $149.1 $2.5 $28.9 $0.8 More than 12 months 0.1 — — — Total $149.2 $2.5 $28.9 $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 June 30, 2021 and December 31, 2020 were as follows: 2021 2020 (In Millions) Less than 1 year $— ($1.1) 1 year - 5 years 144.0 134.7 5 years - 10 years 147.3 141.5 10 years - 15 years 46.3 31.5 15 years - 20 years 2.8 5.3 20 years+ 127.4 115.8 Total $467.8 $427.7

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2021
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—
Entergy Arkansas [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—
Entergy Louisiana [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—
Entergy New Orleans [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—
Entergy Texas [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—
System Energy [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows: Three Months Six Months 2021 2020 2021 2020 (In Millions) Entergy $14 $15 $54 $45 Entergy Arkansas $— ($1) $8 $12 Entergy Louisiana $8 $8 $15 $16 Entergy New Orleans $— $2 $— $5 Entergy Texas $6 $6 $13 $12 System Entergy $— $— $18 $—

Revenue Recognition Revenue Rec

Revenue Recognition Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2021
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $855,586 $790,869 Commercial 628,703 526,121 Industrial 756,959 576,203 Governmental 61,612 46,959 Total billed retail 2,302,860 1,940,152 Sales for resale (a) 119,130 52,761 Other electric revenues (b) 187,078 168,721 Revenues from contracts with customers 2,609,068 2,161,634 Other revenues (c) 32,307 28,923 Total electric revenues 2,641,375 2,190,557 Natural gas 31,998 22,495 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 146,680 175,720 Other revenues (c) 2,017 24,016 Total competitive businesses revenues 148,697 199,736 Total operating revenues $2,822,070 $2,412,788 Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 2020 (In Thousands) Utility: Residential $1,822,441 $1,588,897 Commercial 1,201,380 1,065,061 Industrial 1,354,610 1,133,718 Governmental 118,409 99,541 Total billed retail 4,496,840 3,887,217 Sales for resale (a) 324,205 106,487 Other electric revenues (b) 267,339 218,887 Revenues from contracts with customers 5,088,384 4,212,591 Other revenues (c) 91,410 28,605 Total electric revenues 5,179,794 4,241,196 Natural gas 90,166 66,471 Entergy Wholesale Commodities: Competitive businesses sales from contracts with customers (a) 378,794 391,723 Other revenues (c) 18,153 140,577 Total competitive businesses revenues 396,947 532,300 Total operating revenues $5,666,907 $4,839,967
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,103 $340,643 $117,461 $60,186 $166,193 Commercial 111,187 262,351 101,644 51,092 102,429 Industrial 114,284 475,185 36,545 8,028 122,917 Governmental 4,536 21,547 10,873 18,312 6,344 Total billed retail 401,110 1,099,726 266,523 137,618 397,883 Sales for resale (a) 69,750 74,343 44,050 12,810 19,542 Other electric revenues (b) 73,209 55,745 36,390 9,510 13,577 Revenues from contracts with customers 544,069 1,229,814 346,963 159,938 431,002 Other revenues (c) 6,205 24,765 2,077 (177) (568) Total electric revenues 550,274 1,254,579 349,040 159,761 430,434 Natural gas — 13,019 — 18,979 — Total operating revenues $550,274 $1,267,598 $349,040 $178,740 $430,434 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $171,171 $301,105 $112,361 $53,420 $152,811 Commercial 106,104 209,119 89,594 36,401 84,904 Industrial 106,254 335,201 35,874 3,066 95,809 Governmental 4,344 16,781 9,798 10,475 5,560 Total billed retail 387,873 862,206 247,627 103,362 339,084 Sales for resale (a) 36,956 82,698 18,426 8,018 13,187 Other electric revenues (b) 63,537 53,104 29,393 3,999 20,039 Revenues from contracts with customers 488,366 998,008 295,446 115,379 372,310 Other revenues (c) 3,401 3,593 2,508 19,520 (116) Total electric revenues 491,767 1,001,601 297,954 134,899 372,194 Natural gas — 10,051 — 12,444 — Total operating revenues $491,767 $1,011,652 $297,954 $147,343 $372,194 The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows: 2021 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $408,284 $676,403 $265,097 $126,613 $346,044 Commercial 217,603 487,000 199,580 98,891 198,306 Industrial 217,696 822,194 70,524 14,817 229,379 Governmental 8,791 40,163 21,416 34,692 13,347 Total billed retail 852,374 2,025,760 556,617 275,013 787,076 Sales for resale (a) 179,834 154,771 84,360 17,506 93,615 Other electric revenues (b) 92,791 99,654 40,341 6,151 31,106 Revenues from contracts with customers 1,124,999 2,280,185 681,318 298,670 911,797 Other revenues (c) 8,661 54,057 4,341 239 (1,143) Total electric revenues 1,133,660 2,334,242 685,659 298,909 910,654 Natural gas — 41,000 — 49,166 — Total operating revenues $1,133,660 $2,375,242 $685,659 $348,075 $910,654 2020 Entergy Entergy Entergy Entergy Entergy (In Thousands) Residential $390,859 $560,965 $239,463 $104,319 $293,291 Commercial 217,349 411,365 186,392 81,905 168,050 Industrial 207,342 657,542 72,264 10,413 186,157 Governmental 8,374 33,535 20,125 26,326 11,180 Total billed retail 823,924 1,663,407 518,244 222,963 658,678 Sales for resale (a) 78,096 161,228 32,848 18,188 21,815 Other electric revenues (b) 65,134 85,113 35,836 4,763 30,742 Revenues from contracts with customers 967,154 1,909,748 586,928 245,914 711,235 Other revenues (c) 6,525 4,394 4,948 12,416 295 Total electric revenues 973,679 1,914,142 591,876 258,330 711,530 Natural gas — 28,157 — 38,315 — Total operating revenues $973,679 $1,942,299 $591,876 $296,645 $711,530
Allowance for Doubtful Accounts	The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 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 25.9 5.5 11.7 1.7 4.6 2.4 Write-offs (39.5) (2.8) (19.5) (8.8) (1.1) (7.3) Recoveries 5.0 1.4 1.9 1.2 0.2 0.3 Balance as of June 30, 2021 $109.1 $22.4 $39.8 $13.6 $21.1 $12.2 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 38.4 6.3 14.1 7.0 5.5 5.5 Write-offs (8.6) (1.8) (3.5) (1.2) (1.0) (1.1) Recoveries 6.0 1.6 2.0 0.8 0.7 0.9 Balance as of June 30, 2020 $43.2 $7.3 $14.5 $7.2 $8.4 $5.8

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	Jan. 31, 2021	Jun. 30, 2021	Jun. 30, 2020
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 15,735	$ 67,252
Entergy Louisiana [Member]
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		0	5,090
Entergy Arkansas [Member]
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 0	$ 55,001
Entergy Wholesale Commodities [Member] | Palisades [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 23,100
Damages awarded for previously recorded operation and maintenance	7,100
Damages awarded for previously capitalized costs	15,700
Damages awarded for previously recorded taxes other than income taxes	300
Reduction of previously recorded deprecation expense	$ 9,100

Rate And Regulatory Matters (Na

Rate And Regulatory Matters (Narrative) (Details) - USD ($)	1 Months Ended									6 Months Ended		8 Months Ended			12 Months Ended				14 Months Ended	24 Months Ended		36 Months Ended
	Jul. 31, 2021	Jun. 30, 2021	Apr. 30, 2021	Mar. 31, 2021	Feb. 28, 2021	Dec. 31, 2020	Nov. 30, 2020	Oct. 31, 2020	May 31, 2019	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2021	Feb. 28, 2021	Aug. 31, 2020	Dec. 31, 2022	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2020	Aug. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2022	Jul. 30, 2021	Apr. 30, 2020
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use										$ 345,339,000	$ 11,735,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 1,383,758,000				$ 2,012,030,000				1,383,758,000								$ 2,012,030,000
Proceeds from the issuance of long-term debt										5,008,330,000	5,201,010,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		63,000,000							$ 109,500,000	63,000,000
Regulatory asset related to costs associated with COVID-19 pandemic		54,700,000								54,700,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 577,975,000				667,281,000				577,975,000								667,281,000
Proceeds from the issuance of long-term debt										2,097,214,000	1,401,887,000
Amount transfer from restricted escrow account as storm damage reserve							$ 257,000,000
Storm Reserve Escrow Account			$ 290,000,000
Estimated remaining costs for completion of J. Wayne Leonard Power Station										3,100,000
Earned return on common equity		8.45%
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		$ 50,700,000
Entergy Louisiana [Member] | Hurricanes Laura, Delta, Zeta, and Winter Storm Uri [Domain]
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System			2,060,000,000
Non-capital storm costs			380,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent			1,680,000,000
Total Restoration Costs For Repair and Replacement of Electrical System including carrying costs			2,110,000,000
Entergy Louisiana [Member] | Mortgage Bonds Zero Point Six Two Percent Series Due November 2023
Regulatory Assets [Line Items]
Proceeds from the issuance of long-term debt							$ 1,100,000,000
Debt instrument, interest rate, stated percentage							0.62%
Entergy Louisiana [Member] | Winter Storm Uri
Regulatory Assets [Line Items]
Fuel Costs					$ 166,000,000
Entergy Louisiana [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Distribution recovery mechanism - amount per year																						$ 225,000,000
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent																						21.00%
Formula rate plan revenue increase limit - exclusive of riders																				$ 70,000,000
Deferral of expenditures on vegetation management																					$ 7,000,000
Authorized return on common equity																						9.50%
Aggregate principal amount of system restoration bonds authorization requested																							$ 2,180,000,000
Entergy Louisiana [Member] | Subsequent Event [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Authorized return on common equity																						9.00%
Entergy Louisiana [Member] | Subsequent Event [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Authorized return on common equity																						10.00%
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 95,400,000
Rate Increase Included in Formula Rate Plan				$ 44,300,000
Regulatory asset related to costs associated with COVID-19 pandemic		19,300,000								19,300,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		$ 172,783,000				134,854,000				172,783,000								134,854,000
Proceeds from the issuance of long-term debt										200,543,000	165,408,000
Public Utilities, Requested Return on Equity, Percentage		6.12%		6.69%
Cap on 2020 retail revenues				2.00%
Demand side management costs				$ 3,900,000
Interim increase in formula rate plan revenues				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
Formula rate plan revenue increase including demand side management costs		48,200,000		$ 48,200,000
Public Utilities, Approved Rate Increase (Decrease), Amount		17,500,000
Formula rate plan increase related to COVID-19 non-bad debt expense		3,700,000
Regulatory asset to reflect terms of joint stipulation		19,900,000								19,900,000
Entergy Mississippi [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Percentage				4.00%
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
public utilities proposed customer credits													$ 100
Regulatory asset related to costs associated with COVID-19 pandemic		13,800,000								13,800,000
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, Property, Plant and Equipment, Construction Work in Progress		29,053,000				12,460,000				29,053,000								$ 12,460,000
Credits to customer bills resulting from City Council Cares Program		4,300,000								4,300,000
Proceeds from the issuance of long-term debt										0	138,939,000
Authorized return on common equity																		9.35%
Storm Reserve Escrow Account		38,846,000				83,038,000				38,846,000								$ 83,038,000
Withdrawal from storm reserves				$ 44,000,000
Earned return on common equity																		6.26%
Entergy New Orleans [Member] | Hurricane Zeta [Domain]
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System			36,000,000
Non-capital storm costs			8,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent			28,000,000
Entergy New Orleans [Member] | Maximum [Member]
Regulatory Assets [Line Items]
public utilities proposed customer credits													$ 400
Entergy New Orleans [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 64,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	40,000,000
Public Utilities, Approved Rate Increase (Decrease), Amount	5,200,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	18,800,000
Public Utilities, Approved Rate Increase (Decrease), Amount	300,000
Entergy Texas [Member]
Regulatory Assets [Line Items]
Regulatory asset related to costs associated with COVID-19 pandemic		14,200,000								14,200,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		181,473,000				879,908,000				181,473,000								$ 879,908,000
Proceeds from the issuance of long-term debt										0	194,256,000
Entergy Texas [Member] | Hurricanes Laura and Delta and Winter Storm Uri
Regulatory Assets [Line Items]
Total Restoration Costs For Repair and Replacement of Electrical System			250,000,000
Non-capital storm costs			50,000,000
Deferred Storm and Property Reserve Deficiency, Noncurrent			$ 200,000,000
Entergy Texas [Member] | Hurricane Laura [Member]
Regulatory Assets [Line Items]
Interim fuel refund for cumulative over-recovery					$ 75,000,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount																		19,400,000
Energy Cost Recovery Rider Rate Per kWh																	$ 0.01052
Regulatory asset related to costs associated with COVID-19 pandemic		11,200,000								11,200,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		319,379,000				234,213,000				319,379,000								234,213,000
Proceeds from the issuance of long-term debt										694,137,000	335,902,000
Provision for rate refund						43,500,000												$ 43,500,000
Public Utilities, Requested Return on Equity, Percentage			9.65%	9.75%
Earned return on common equity																		7.92%
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 108,700,000														$ 89,200,000
Energy Cost Recovery Rider Rate Per kWh																$ 0.00959
Net change in required FRP rider revenue												$ 39,800,000
Public Utilities, Requested Return on Equity, Percentage															7.65%
Annual revenue constraint per rate class percentage	4.00%
Reduced proposed increase in revenue requirement to comply with annual revenue constraint	$ 72,600,000
System Energy [Member]
Regulatory Assets [Line Items]
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
Interest Portion of rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback		119,000,000								119,000,000
Refund related to depreciation expense adjustments		19,000,000								19,000,000
Public Utilities, Property, Plant and Equipment, Construction Work in Progress		75,019,000				59,831,000				75,019,000								$ 59,831,000
Proceeds from the issuance of long-term debt										453,981,000	$ 482,533,000
Authorized return on common equity				10.94%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal				9.32%
Percent Equity in Proposed Common Equity Ratio				48.15%
Estimated refund related to FERC proceeding		59,000,000								59,000,000
Estimated annual rate reduction		46,000,000								46,000,000
Provision related to FERC proceeding		37,000,000								$ 37,000,000
One-time accumulated deferred income tax credit						25,200,000
Sale Leaseback Transaction, Net Book Value																								$ 70,000,000
Grand Gulf [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage										11.50%
Requested refund of alleged replacement energy costs				$ 360,000,000
Grand Gulf [Member] | System Energy [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Proposed limit on capital improvement project costs before pre-authorization is required				$ 125,000,000
Legacy Entergy Louisiana [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		27,000,000
Legacy Entergy Gulf States Louisiana [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		$ 23,700,000
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount								$ 26,300,000
Revenue increase resulting from incremental revenue														$ 6,800,000
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount								51,000,000
Revenue increase resulting from incremental revenue																			$ 31,600,000
Generation Cost Recovery Rider | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount						$ 86,000,000		$ 91,000,000

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jul. 30, 2021	Jun. 30, 2021	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	May 01, 2021	Apr. 30, 2021	Dec. 31, 2020
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation			1,000,000	500,000	1,000,000	500,000
Shares, Issued		265,468	265,468		265,468
Common stock dividend (in dollars per share)			$ 0.95	$ 0.93	$ 1.90	$ 1.86
Shares Issued, Price Per Share		$ 106.87	$ 106.87		$ 106.87
Equity Distribution Sales Agreement, Maximum Aggregate Gross Sales Price [Abstract]		$ 1,000	$ 1,000		$ 1,000
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		499,000,000	499,000,000		499,000,000		499,000,000	500,000,000	499,000,000
Preferred Stock, Shares Authorized		1,000,000	1,000,000		1,000,000		1,000,000		0
Equity Distribution Sales Agreement, Net Sales Price					$ 26.8
Equity Distribution Sales Agreement, Gross Sales Price					28.2
Equity Distribution Sales Agreement, Aggregate Compensation to Sales Agents					0.3
Equity Distribution Sales Agreement, General Issuance Costs					$ 1.1
Forward Sale Agreement, Equity Offering Shares		416,853	416,853		416,853
Forward Sale Agreement, Gross Sales Price		$ 45
Forward Sale Agreement, Aggregate Compensation to Sales Agents		$ 0.5
Stock Issued During Period, Shares, Treasury Stock Reissued					443,060
System Energy [Member]
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		1,000,000	1,000,000		1,000,000				1,000,000
Entergy Texas [Member]
Forward Sale Agreement, Aggregate Compensation to Sales Agents [Abstract]
Common Stock, Shares Authorized		200,000,000	200,000,000		200,000,000				200,000,000
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.95

Equity (Schedule Of Earnings Pe

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	0	300,000	400,000	500,000
Stock options $/share	$ 0	$ 0	$ (0.01)	$ (0.01)
Restricted stock, Shares	0	400,000	300,000	400,000
Restricted stock $/share	$ 0	$ (0.01)	$ 0	$ 0
Basic earnings per share
Net Income (Loss) Available to Common Stockholders, Basic	$ (5,974)	$ 360,533	$ 328,591	$ 479,247
Net Income (Loss) Available to Common Stockholders, Diluted	$ (6,000)	$ 360,500	$ 328,600	$ 479,200
Net Income Attributable to Entergy Corporation, Shares	200,775,395	200,178,010	200,651,162	199,984,013
Net Income Attributable to Entergy Corporation, $/share	$ (0.03)	$ 1.80	$ 1.64	$ 2.40
Diluted earnings per share, Shares	200,775,395	200,886,749	201,352,830	200,891,134
Diluted earnings per share $/share	$ (0.03)	$ 1.79	$ 1.63	$ 2.39

Equity (Accumulated Other Compr

Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	$ (478,739)	$ (500,507)	$ (388,604)	$ (398,987)	$ (478,739)	$ (388,604)	$ (449,207)	$ (446,920)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	634		27,435		(43,186)	171,980
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	21,134		(17,052)		13,654	(113,664)
Other comprehensive income (loss)	21,768	(51,300)	10,383	47,933	(29,532)	58,316
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	11,855	11,963	60,255	41,690	11,855	60,255	56,650	25,946
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	648		22,545		(44,653)	40,258
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(756)		(3,980)		(142)	(5,949)
Other comprehensive income (loss)	(108)		18,565		(44,795)	34,309
Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	21,768	(51,300)	10,383	47,933
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(489,511)	(511,609)	(485,949)	(503,173)	(489,511)	(485,949)	(534,576)	(557,072)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0		0		0	34,349
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	22,098		17,224		45,065	36,774
Other comprehensive income (loss)	22,098		17,224		45,065	71,123
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(1,083)	(861)	37,090	62,496	(1,083)	37,090	28,719	84,206
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(14)		4,890		1,467	97,373
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(208)		(30,296)		(31,269)	(144,489)
Other comprehensive income (loss)	(222)		(25,406)		(29,802)	(47,116)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	4,508				4,508		4,327
Other comprehensive income (loss)	588	(407)	(945)	9,467	181	8,522
Entergy Louisiana [Member] | Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	588	(407)	(945)	9,467
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	4,508	$ 3,920	13,084	$ 14,029	4,508	13,084	$ 4,327	$ 4,562
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax					0	10,050
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	588		(945)		181	(1,528)
Other comprehensive income (loss)	$ 588		$ (945)		$ 181	$ 8,522

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2021	Jun. 30, 2020
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,822,070		$ 2,412,788		$ 5,666,907	$ 4,839,967
Other Nonoperating Income (Expense)	(62,844)		(93,620)		(123,773)	(70,232)
Income taxes (benefits)	18,416		(89,115)		(47,526)	(17,921)
Consolidated net income	(1,394)	$ 339,145	365,113	$ 123,294	337,750	488,406
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	148,697		199,736		396,947	532,300
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(21,134)		17,052		(13,654)	113,664
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(48)		(48)		(97)	(97)
INCOME (LOSS) BEFORE INCOME TAXES	264		25,038		39,582	119,412
Income taxes (benefits)	(56)		5,258		(8,313)	25,077
Consolidated net income	208		30,296		31,269	144,489
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	312		25,086		39,679	119,509
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income taxes (benefits)	(440)		(2,317)		(82)	(3,464)
Consolidated net income	756		3,980		142	5,949
Realized Investment Gains (Losses)	1,196		6,297		224	9,413
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	5,248		5,682		10,496	9,401
Amortization of loss	(27,534)		(27,619)		(62,063)	(54,937)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(6,043)		0		(6,043)	0
INCOME (LOSS) BEFORE INCOME TAXES	(28,329)		(21,937)		(57,610)	(45,536)
Income taxes (benefits)	6,231		4,713		12,545	8,762
Consolidated net income	(22,098)		(17,224)		(45,065)	(36,774)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,267,598		1,011,652		2,375,242	1,942,299
Other Nonoperating Income (Expense)	(36,033)		(66,811)		(70,671)	(17,210)
Income taxes (benefits)	(26,171)		(35,910)		(63,943)	14,273
Consolidated net income	143,927	$ 166,626	170,459	$ 189,396	310,553	359,855
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	1,230		1,698		2,460	2,787
Amortization of loss	(626)		(419)		(1,305)	(720)
Defined Benefit Plan, Accumulated Benefit Obligation, (Increase) Decrease for Settlement and Curtailment	(1,400)		0		(1,400)	0
INCOME (LOSS) BEFORE INCOME TAXES	(796)		1,279		(245)	2,067
Income taxes (benefits)	208		(334)		64	(539)
Consolidated net income	$ (588)		$ 945		$ (181)	$ 1,528

Revolving Credit Facilities, _3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) $ in Thousands	1 Months Ended				6 Months Ended
	Jun. 30, 2021USD ($)	May 31, 2021USD ($)	Apr. 30, 2021USD ($)	Mar. 31, 2021USD ($)	Jun. 30, 2021USD ($)	May 01, 2021	Dec. 31, 2020USD ($)
Debt Instrument [Line Items]
Amount of Facility	$ 3,500,000				$ 3,500,000
Amount Drawn/ Outstanding	$ 150,000				$ 150,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate	0.32%				0.32%
Commercial Paper program limit	$ 2,000,000				$ 2,000,000
Commercial Paper Amount Outstanding	866,000				866,000
Credit Facility [Member]
Debt Instrument [Line Items]
Amount of Facility	3,500,000				3,500,000
Amount of total borrowing capacity against which fronting commitments exist	20,000				$ 20,000
Line of credit facility, commitment fee percentage					0.225%
Line of Credit Facility, Interest Rate During Period					1.61%
1.90% Series senior notes due June 2028
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				1.90%
Amount				$ 650,000
2.40% Series senior notes due June 2031
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				2.40%
Amount				$ 650,000
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	250,000				$ 250,000
Amount of total borrowing capacity against which fronting commitments exist	5,000				5,000
Letters of Credit Outstanding, Amount	1,500				1,500
Entergy Arkansas [Member] | Revolving Credit Facility
Debt Instrument [Line Items]
Amount of Facility				150,000
Entergy Arkansas [Member] | Short-term revolving credit facility
Debt Instrument [Line Items]
Amount of Facility				$ 25,000
Entergy Arkansas [Member] | 3.35% Series mortgage bonds due June 2052
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				3.35%
Proceeds from Issuance of Debt				$ 400,000
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	450,000				450,000
Amount of total borrowing capacity against which fronting commitments exist	15,000				15,000
Letters of Credit Outstanding, Amount	700				700		$ 300
Entergy Louisiana [Member] | 2.35% Series mortgage bonds due June 2032
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				2.35%
Proceeds from Issuance of Debt				$ 500,000
Entergy Louisiana [Member] | 4.80% Series mortgage bonds due May 2021
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				4.80%
Repayments of Debt				$ 200,000
Entergy Louisiana [Member] | 3.10% Series mortgage bonds due June 2041
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				3.10%
Proceeds from Issuance of Debt				$ 500,000
Entergy Louisiana [Member] | 2.00% pollution control refunding revenue bonds due June 2030
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.00%
Proceeds from Issuance of Debt			$ 16,200
Entergy Louisiana [Member] | 2.50% pollution control refunding revenue bonds due April 2036
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			2.50%
Proceeds from Issuance of Debt			$ 182,480
Entergy Louisiana [Member] | 3.375% Pollution contol refunding revenue bonds due 2028
Debt Instrument [Line Items]
Repayments of Debt			83,680
Entergy Louisiana [Member] | 3.50% Pollution control refunding revenue bond due 2030
Debt Instrument [Line Items]
Repayments of Debt			$ 115,000
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	175,000				175,000
Letters of Credit Outstanding, Amount	900				900		200
Non-MISO letter of credit outstanding	7,900				7,900
Entergy Mississippi [Member] | 3.50% Series mortgage bonds due June 2051 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				3.50%
Proceeds from Issuance of Debt				$ 200,000
Entergy Mississippi [Member] | Revolving Credit Facility
Debt Instrument [Line Items]
Amount of Facility				$ 82,500
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	200,000				200,000
Amount of total borrowing capacity against which fronting commitments exist	30,000				30,000
Letters of Credit Outstanding, Amount	2,300				2,300		500
Entergy Texas [Member] | 2.55% Series mortgage bonds due June 2021 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage						2.55%
Repayments of Debt		$ 125,000
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	$ 200,000				$ 200,000
System Energy [Member] | 2.375% refunding revenue bonds due June 2044
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	2.375%				2.375%
Proceeds from Issuance of Debt	$ 83,695
System Energy [Member] | Outstanding revenue bonds
Debt Instrument [Line Items]
Repayments of Debt	83,695
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	150,000				$ 150,000
Amount of total borrowing capacity against which fronting commitments exist	10,000				10,000
Letters of Credit Outstanding, Amount	300				300		$ 200
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	45,700				$ 45,700
Line of Credit Facility, Interest Rate During Period					1.22%
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 0				$ 0
Line of Credit Facility, Interest Rate During Period					1.26%
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.65%				3.65%
Amount	$ 90,000				$ 90,000
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	62,100				$ 62,100
Line of Credit Facility, Interest Rate During Period					1.22%
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	64,600				$ 64,600
Line of Credit Facility, Interest Rate During Period					1.22%
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.10%
Entergy Nuclear Vermont Yankee
Debt Instrument [Line Items]
Amount of Facility	139,000				$ 139,000
Amount Drawn/ Outstanding	$ 139,000				$ 139,000
Debt, weighted average interest rate	1.71%				1.71%
Line of credit facility commitment fee as a percentage of undrawn commitment amount					0.20%
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage					0.275%
Consolidated debt ratio	0.65				0.65
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Consolidated debt ratio of total capitalization					70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65				0.65
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage					0.075%
Credit Facility Of Three Hundred Fifty Million [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Amount of Facility	$ 350,000				$ 350,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.23%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	150,000				$ 150,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.23%
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility	150,000				$ 150,000
Letters of Credit Outstanding, Amount	1,300				1,300
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.60%
Credit Facility Of Thirty Seven Point Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	37,500				$ 37,500
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.60%
Credit Facility Of Thirty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	35,000				$ 35,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.60%
Credit Facility Of Ten Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	10,000				$ 10,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.60%
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	25,000				$ 25,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					2.75%
Credit Facility Of Twenty Five Million [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Amount of Facility	25,000				$ 25,000
Letters of Credit Outstanding, Amount	0				0
Amount Drawn/ Outstanding	0				$ 0
Line of Credit Facility, Interest Rate During Period					1.58%
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount	2,000				$ 2,000
Uncommitted Credit Facility	$ 65,000				$ 65,000

Revolving Credit Facilities, _4

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) $ in Millions	Jun. 30, 2021USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	150
Letters of Credit	6
Capacity Available	$ 3,344

Revolving Credit Facilities, _5

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Dec. 31, 2020
Amount of Facility	$ 3,500
Amount Drawn/ Outstanding	150
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	5
Letters of Credit Outstanding, Amount	1.5
Entergy Arkansas [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 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]
Amount of Facility	$ 150
Interest Rate	1.23%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	15
Letters of Credit Outstanding, Amount	0.7	$ 0.3
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Amount of Facility	$ 350
Interest Rate	1.23%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.9	0.2
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Amount of Facility	$ 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]
Amount of Facility	$ 35
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Amount of Facility	$ 10
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	10
Letters of Credit Outstanding, Amount	0.3	0.2
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Amount of Facility	$ 25
Interest Rate	1.58%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	30
Letters of Credit Outstanding, Amount	2.3	$ 0.5
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Amount of Facility	$ 150
Interest Rate	1.60%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1.3

Revolving Credit Facilities, _6

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Jun. 30, 2021USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	0
Entergy Louisiana [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	175
Borrowings	17
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	38
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	63
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

Revolving Credit Facilities, _7

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 150
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 80
Line of Credit Facility, Interest Rate During Period	1.26%
Amount Drawn/ Outstanding	$ 0
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 120
Line of Credit Facility, Interest Rate During Period	1.22%
Amount Drawn/ Outstanding	$ 45.7
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	1.22%
Amount Drawn/ Outstanding	$ 64.6
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount of Facility	$ 105
Line of Credit Facility, Interest Rate During Period	1.22%
Amount Drawn/ Outstanding	$ 62.1
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

Revolving Credit Facilities, _8

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Jun. 30, 2021USD ($)
Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.65%
Amount	$ 90
Three Point One Seven Percent Series M Notes Due December Two Thousand Twenty Three [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.17%
Amount	$ 40
Three Point Two Two Percent Series I Notes Due December Two Thousand Twenty Three [Domain] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.22%
Amount	$ 20
Two Point Fifty One Percent Series V Notes Due June 2027 | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	2.51%
Amount	$ 70
Two Point Zero Five Percent Series K Notes Due September 2027 | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	2.05%
Amount	$ 90
One Point Eight Four Percent Series N Notes Due July Two Thousand Twenty Six | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	1.84%
Amount	$ 90

Revolving Credit Facilities, _9

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Long-term Debt, Fair Value	$ 26,221,663	$ 24,813,818
Long-term Debt, Book Value	24,497,290	22,369,776
Entergy Arkansas [Member]
Long-term Debt, Fair Value	4,327,356	4,355,632
Long-term Debt, Book Value	4,043,714	3,967,507
Entergy Louisiana [Member]
Long-term Debt, Fair Value	10,746,564	10,258,294
Long-term Debt, Book Value	9,836,133	9,027,451
Entergy Mississippi [Member]
Long-term Debt, Fair Value	2,166,517	2,021,432
Long-term Debt, Book Value	1,981,674	1,780,577
Entergy New Orleans [Member]
Long-term Debt, Fair Value	584,209	620,634
Long-term Debt, Book Value	636,870	642,233
Entergy Texas [Member]
Long-term Debt, Fair Value	2,496,970	2,765,193
Long-term Debt, Book Value	2,323,879	2,493,708
System Energy [Member]
Long-term Debt, Fair Value	771,477	840,540
Long-term Debt, Book Value	$ 750,939	$ 805,274

Revolving Credit Facilities,_10

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 1.5
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	0.9	$ 0.2
Entergy Louisiana [Member]
Letters of Credit Outstanding, Amount	0.7	0.3
Entergy New Orleans [Member]
Letters of Credit Outstanding, Amount	0.3	0.2
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	2.3	$ 0.5
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 2.5
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 18.2
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 1
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 7.8
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 65
Letter of Credit Fee, Percentage	0.78%
Letters of Credit Outstanding, Amount	$ 2

Stock Based Compensation (Narra

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 28, 2021	Jan. 31, 2021	Mar. 31, 2021	Jun. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years				3 years
2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)			508,704
Weighted-average grant-date fair value of options granted (in dollars per share)			$ 12.27
Stock options outstanding				2,844,446
Weighted-average exercise price of stock options outstanding (in dollars per share)				$ 90.78
Intrinsic value in the money stock options				$ 41.5
Restricted Awards [Member] | 2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted		392,382
Restricted stock awards granted value (in dollars per share)		$ 95.87
Long Term Incentive Plan [Member] | 2019 Omnibus Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards		203,983
Percent of performance measure based on relative total shareholder return	80.00%			80.00%
Percent of performance measure based on cumulative adjusted EPS metric	20.00%			20.00%
Long Term Incentive Plan [Member] | 2019 Omnibus Incentive Plan | Performance measure based on relative total shareholder return [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 110.74
Long Term Incentive Plan [Member] | 2019 Omnibus Incentive Plan | Performance measure based on cumulative adjusted earnings per share metric [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 95.87

Stock-Based Compensation (Finan

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 1	$ 1	$ 2	$ 2
Tax benefit recognized in Entergy's net income	0.2	0.2	0.5	0.5
Compensation cost capitalized as part of fixed assets and inventory	$ 0.4	$ 0.4	$ 0.8	$ 0.8

Stock-Based Compensation (Fin_2

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 9.7	$ 9.6	$ 20.5	$ 19
Tax benefit recognized in Entergy's net income	2.5	2.5	5.2	4.9
Compensation cost capitalized as part of fixed assets and inventory	$ 4	$ 3.8	$ 8	$ 7.2

Retirement And Other Postreti_3

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2021	Jun. 30, 2021	Jun. 30, 2020
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	$ 356,000			$ 356,000
Defined Benefit Plan, Plan Assets, Contributions by Employer				220,100
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	66,649			66,649
Defined Benefit Plan, Plan Assets, Contributions by Employer				36,457
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	59,882			59,882
Defined Benefit Plan, Plan Assets, Contributions by Employer				39,400
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	13,715			13,715
Defined Benefit Plan, Plan Assets, Contributions by Employer				7,771
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	5,395			5,395
Defined Benefit Plan, Plan Assets, Contributions by Employer				3,551
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	6,955			6,955
Defined Benefit Plan, Plan Assets, Contributions by Employer				4,275
Difference between rate case pension amounts and actuarially determined pension amounts	10,100			10,100
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year	18,663			18,663
Defined Benefit Plan, Plan Assets, Contributions by Employer				10,671
Subsequent Event [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 30,192
Subsequent Event [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			20,482
Subsequent Event [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			5,944
Subsequent Event [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			1,844
Subsequent Event [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			2,680
Subsequent Event [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer			$ 7,992
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	4,600	$ 4,500		9,200	$ 9,100
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	90	83		180	166
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	44	37		88	74
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	96	90		192	180
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	8	8		16	16
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	115	117		230	234
Pension Plans Defined Benefit [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	188,642	84,872		278,657	169,744
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	111,549	0		111,549	0
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	39,003	15,274		54,393	30,548
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	24,386			24,386
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	49,989	15,860		66,258	31,720
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	34,992			34,992
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	12,346	4,354		17,254	8,708
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	7,762			7,762
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	4,866	1,497		6,339	2,994
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	3,585			3,585
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	8,578	2,107		10,801	4,214
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	6,626			6,626
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net other postretirement benefit cost	9,256	$ 4,395		14,257	$ 8,790
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	$ 4,638			$ 4,638

Retirement And Other Postreti_4

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 42,951	$ 40,379	$ 88,191	$ 80,758
Interest cost on projected benefit obligation	47,382	60,799	93,480	121,598
Expected return on assets	(106,039)	(103,565)	(211,753)	(207,130)
Amortization of loss	92,799	87,259	197,190	174,518
Net other postretirement benefit cost	188,642	84,872	278,657	169,744
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	111,549	0	111,549	0
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	7,255	6,566	14,674	13,132
Interest cost on projected benefit obligation	8,752	11,433	17,092	22,866
Expected return on assets	(19,640)	(19,622)	(39,311)	(39,244)
Amortization of loss	18,250	16,897	37,552	33,794
Net other postretirement benefit cost	39,003	15,274	54,393	30,548
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	24,386		24,386
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	9,759	8,794	19,803	17,588
Interest cost on projected benefit obligation	9,864	12,841	19,425	25,682
Expected return on assets	(22,516)	(22,402)	(45,055)	(44,804)
Amortization of loss	17,890	16,627	37,093	33,254
Net other postretirement benefit cost	49,989	15,860	66,258	31,720
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	34,992		34,992
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,304	2,023	4,668	4,046
Interest cost on projected benefit obligation	2,571	3,340	5,034	6,680
Expected return on assets	(5,600)	(5,757)	(11,186)	(11,514)
Amortization of loss	5,309	4,748	10,976	9,496
Net other postretirement benefit cost	12,346	4,354	17,254	8,708
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	7,762		7,762
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	774	663	1,569	1,326
Interest cost on projected benefit obligation	1,079	1,456	2,108	2,912
Expected return on assets	(2,641)	(2,627)	(5,263)	(5,254)
Amortization of loss	2,069	2,005	4,340	4,010
Net other postretirement benefit cost	4,866	1,497	6,339	2,994
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	3,585		3,585
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,757	1,546	3,557	3,092
Interest cost on projected benefit obligation	2,052	2,782	4,002	5,564
Expected return on assets	(5,272)	(5,486)	(10,510)	(10,972)
Amortization of loss	3,415	3,265	7,126	6,530
Net other postretirement benefit cost	8,578	2,107	10,801	4,214
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	6,626		6,626
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	2,253	1,965	4,566	3,930
Interest cost on projected benefit obligation	2,236	2,814	4,378	5,628
Expected return on assets	(4,804)	(4,663)	(9,583)	(9,326)
Amortization of loss	4,933	4,279	10,258	8,558
Net other postretirement benefit cost	9,256	4,395	14,257	8,790
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	4,638		4,638
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	6,645	6,231	13,290	12,032
Interest cost on projected benefit obligation	5,320	6,888	10,640	14,820
Expected return on assets	(10,805)	(10,182)	(21,610)	(20,510)
Amortization of prior service cost (credit)	(8,267)	(8,985)	(16,534)	(14,907)
Amortization of loss	713	1,005	1,426	1,473
Net other postretirement benefit cost	(6,394)	(5,043)	(12,788)	(7,092)
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,034	933	2,068	1,761
Interest cost on projected benefit obligation	932	1,164	1,864	2,381
Expected return on assets	(4,505)	(4,260)	(9,010)	(8,586)
Amortization of prior service cost (credit)	(280)	(396)	(560)	(1,057)
Amortization of loss	49	162	98	217
Net other postretirement benefit cost	(2,770)	(2,397)	(5,540)	(5,284)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,544	1,524	3,088	2,947
Interest cost on projected benefit obligation	1,130	1,497	2,260	3,220
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,230)	(1,695)	(2,460)	(2,784)
Amortization of loss	(91)	(81)	(182)	(280)
Net other postretirement benefit cost	1,353	1,245	2,706	3,103
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	362	372	724	723
Interest cost on projected benefit obligation	278	372	556	794
Expected return on assets	(1,384)	(1,287)	(2,768)	(2,594)
Amortization of prior service cost (credit)	(444)	(444)	(888)	(765)
Amortization of loss	19	48	38	77
Net other postretirement benefit cost	(1,169)	(939)	(2,338)	(1,765)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	109	114	218	219
Interest cost on projected benefit obligation	130	186	260	413
Expected return on assets	(1,438)	(1,344)	(2,876)	(2,699)
Amortization of prior service cost (credit)	(229)	(228)	(458)	(304)
Amortization of loss	(178)	9	(356)	(29)
Net other postretirement benefit cost	(1,606)	(1,263)	(3,212)	(2,400)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	346	306	692	609
Interest cost on projected benefit obligation	317	477	634	1,059
Expected return on assets	(2,548)	(2,403)	(5,096)	(4,838)
Amortization of prior service cost (credit)	(936)	(939)	(1,872)	(1,489)
Amortization of loss	100	231	200	443
Net other postretirement benefit cost	(2,721)	(2,328)	(5,442)	(4,216)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	335	321	670	615
Interest cost on projected benefit obligation	220	276	440	583
Expected return on assets	(789)	(735)	(1,578)	(1,483)
Amortization of prior service cost (credit)	(109)	(282)	(218)	(501)
Amortization of loss	15	33	30	53
Net other postretirement benefit cost	(328)	(387)	(656)	(733)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,600	4,500	9,200	9,100
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	90	83	180	166
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	44	37	88	74
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	96	90	192	180
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	8	8	16	16
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 115	$ 117	$ 230	$ 234

Retirement And Other Postreti_5

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	6 Months Ended
	Dec. 31, 2021	Jun. 30, 2021
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 356,000
Defined Benefit Plan, Plan Assets, Contributions by Employer		220,100
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		59,882
Defined Benefit Plan, Plan Assets, Contributions by Employer		39,400
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 20,482
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		13,715
Defined Benefit Plan, Plan Assets, Contributions by Employer		7,771
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	5,944
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		5,395
Defined Benefit Plan, Plan Assets, Contributions by Employer		3,551
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	1,844
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		6,955
Defined Benefit Plan, Plan Assets, Contributions by Employer		4,275
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,680
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		18,663
Defined Benefit Plan, Plan Assets, Contributions by Employer		10,671
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	7,992
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		66,649
Defined Benefit Plan, Plan Assets, Contributions by Employer		$ 36,457
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 30,192

Retirement And Other Postreti_6

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,248	$ 5,682	$ 10,496	$ 9,401
Amortization of loss	(27,534)	(27,619)	(62,063)	(54,937)
Total	(28,329)	(21,937)	(57,610)	(45,536)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(6,043)		(6,043)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,230	1,698	2,460	2,787
Amortization of loss	(626)	(419)	(1,305)	(720)
Total	(796)	1,279	(245)	2,067
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,400)		(1,400)
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(26,443)	(26,461)	(59,883)	(52,923)
Total	(32,486)	(26,461)	(65,926)	(52,923)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(6,043)		(6,043)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(716)	(499)	(1,484)	(998)
Total	(2,116)	(499)	(2,884)	(998)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(1,400)		(1,400)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,288	5,739	10,576	9,516
Amortization of loss	(496)	(327)	(990)	(352)
Total	4,792	5,412	9,586	9,164
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,230	1,698	2,460	2,787
Amortization of loss	91	81	182	280
Total	1,321	1,779	2,642	3,067
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(40)	(57)	(80)	(115)
Amortization of loss	(595)	(831)	(1,190)	(1,662)
Total	(635)	(888)	(1,270)	(1,777)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0		0
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(1)	(1)	(3)	(2)
Total	(1)	$ (1)	(3)	$ (2)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	$ 0		$ 0

Business Segment Information Bu

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended			12 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2021	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2022
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 342	$ 7		$ 345	$ 12
Restructuring Charges	(5)	17		8	38
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges				7
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			$ 10			$ 5
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ (6)	$ 17		$ 7	$ 38

Business Segment Information (S

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,822,070		$ 2,412,788		$ 5,666,907	$ 4,839,967
Segment Financial Information
Income taxes (benefits)	(18,416)		89,115		47,526	17,921
Consolidated net income	(1,394)	$ 339,145	365,113	$ 123,294	337,750	488,406
Assets	55,949,283				55,949,283		$ 58,239,212
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,673,385		2,213,061		5,270,000	4,307,690
Segment Financial Information
Income taxes (benefits)	71,360		73,710		131,094	20,761
Consolidated net income	329,936		348,902		690,535	672,751
Assets	56,240,370				56,240,370		55,940,153
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	148,656		199,709		396,874	532,258
Segment Financial Information
Income taxes (benefits)	(71,696)		24,467		(56,135)	(6,073)
Consolidated net income	(274,648)		85,178		(236,525)	(25,251)
Assets	1,209,209				1,209,209		3,800,378
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	31		18		54	29
Segment Financial Information
Income taxes (benefits)	(18,080)		(9,062)		(27,433)	3,233
Consolidated net income	(24,784)		(37,069)		(52,464)	(95,298)
Assets	496,043				496,043		552,632
Eliminations
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(2)		0		(21)	(10)
Segment Financial Information
Income taxes (benefits)	0		0		0	0
Consolidated net income	(31,898)		$ (31,898)		(63,796)	$ (63,796)
Assets	$ (1,996,339)				$ (1,996,339)		$ (2,053,951)

Business Segment Information _2

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			$ 7
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ (5)	$ 17	8	$ 38
Restructuring Reserve	33	167	33	167	$ 171	$ 159	$ 164	$ 143
Payments for Restructuring	133	14	134	14
Asset Write-Offs, Impairments, And Related Charges	342	7	345	12
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	(6)	17	7	38
Restructuring Reserve	33	153	33	153	157	145	150	129
Payments for Restructuring	118	14	119	14
Entergy Wholesale Commodities [Member] | Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	1	0	1	0
Restructuring Reserve	0	14	0	14	$ 14	$ 14	$ 14	$ 14
Payments for Restructuring	$ 15	$ 0	$ 15	$ 0

Risk Management and Fair Valu_3

Risk Management and Fair Values (Narrative) (Details) TWh in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021USD ($)GWhMMBTU	Jun. 30, 2020USD ($)	Dec. 31, 2021TWh	Jun. 30, 2021USD ($)GWhMMBTU	Jun. 30, 2020USD ($)	Dec. 31, 2020USD ($)
Maturity of cash flow hedges, Tax		$ 5		$ 8	$ 25
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	33,969,600			33,969,600
Total volume of fixed transmission rights outstanding | GWh	126,149			126,149
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings		3			4
Debt Securities, Available-for-sale, Allowance for Credit Loss	$ 0.2			$ 0.2		$ 0.1
Letters Of Credit	6			6
Entergy Arkansas [Member]
Letters of Credit Outstanding, Amount	$ 1.5			$ 1.5
Total volume of fixed transmission rights outstanding | GWh	25,505			25,505
Entergy Louisiana [Member]
Letters of Credit Outstanding, Amount	$ 0.7			$ 0.7		0.3
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	20,100,000			20,100,000
Total volume of fixed transmission rights outstanding | GWh	58,280			58,280
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 0.9			$ 0.9		0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	13,569,000			13,569,000
Total volume of fixed transmission rights outstanding | GWh	14,634			14,634
Entergy New Orleans [Member]
Letters of Credit Outstanding, Amount	$ 0.3			$ 0.3		0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU	300,600			300,600
Total volume of fixed transmission rights outstanding | GWh	5,842			5,842
Entergy Texas [Member]
Letters of Credit Outstanding, Amount	$ 2.3			$ 2.3		0.5
Total volume of fixed transmission rights outstanding | GWh	21,399			21,399
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge				2 years 9 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge				9 months
Gas Hedge Contracts [Member] | Entergy New Orleans [Member]
Maximum Length of Time Hedged in Cash Flow Hedge				9 months
Electricity Swaps And Options [Member] | Cash Flow Hedging [Member] | Competitive Businesses Operating Revenues [Member]
Maturity of cash flow hedges, before taxes	$ 0	$ 25		$ 40	$ 120
Entergy Wholesale Commodities [Member]
Cash collateral posted	5			5		5
Letters of Credit Held						39
Utility [Member]
Letters Of Credit	$ 6			$ 6		$ 1
Subsequent Event [Member]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period			98.00%
Total planned generation for remainder of the period | TWh			3.4

Risk Management and Fair Valu_4

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 5	$ 5
Liabilities:
Letters of Credit Held		39
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, Collateral, Right to Reclaim Cash		0
Derivative Liability		1
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		1
Derivative Asset, Fair Value, Gross Asset		1
Derivative, Collateral, Obligation to Return Cash		0
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		38
Derivative Asset, Fair Value, Gross Asset		39
Derivative, Collateral, Obligation to Return Cash		(1)
Prepayments And Other [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	15	1
Derivative Asset, Fair Value, Gross Asset	15	1
Derivative, Collateral, Obligation to Return Cash	0	0
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	15	9
Derivative Asset, Fair Value, Gross Asset	16	9
Derivative, Collateral, Obligation to Return Cash	(1)	0
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		1
Derivative, Collateral, Right to Reclaim Cash		(1)
Derivative Liability		0
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		6
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		6
Entergy Louisiana [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.7	0.3
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.4	0.5
Derivative Asset, Fair Value, Gross Asset	0.4	0.5
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	5	0.8
Derivative Asset, Fair Value, Gross Asset	5	0.8
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	4.8	4.2
Derivative Asset, Fair Value, Gross Asset	4.9	4.3
Derivative, Collateral, Obligation to Return Cash	0.1	(0.1)
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, Collateral, Right to Reclaim Cash		0
Derivative Liability		0.3
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.9	0.2
Entergy Mississippi [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	9.6
Derivative Asset, Fair Value, Gross Asset	9.6
Derivative, Collateral, Obligation to Return Cash	0
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	2	0.6
Derivative Asset, Fair Value, Gross Asset	2	0.6
Derivative, Collateral, Obligation to Return Cash	0	0
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		5
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		5
Entergy New Orleans [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.3	0.2
Entergy New Orleans [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.1
Derivative Asset, Fair Value, Gross Asset	0.1
Derivative, Collateral, Obligation to Return Cash	0
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.6	0.1
Derivative Asset, Fair Value, Gross Asset	0.6	0.2
Derivative, Collateral, Obligation to Return Cash	0	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		0.3
Derivative, Collateral, Right to Reclaim Cash		0
Derivative Liability		0.3
Entergy Arkansas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	1.5
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3.8	2.7
Derivative Asset, Fair Value, Gross Asset	4.1	2.9
Derivative, Collateral, Obligation to Return Cash	(0.3)	(0.2)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount	2.3	0.5
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3.8	1.6
Derivative Asset, Fair Value, Gross Asset	3.8	1.6
Derivative, Collateral, Obligation to Return Cash	$ 0	$ 0

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 Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ 0	$ (7)	$ 2	$ 60
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 0	$ 25	$ 40	$ 120

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) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0	$ (2)	$ (2)	$ (2)
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	18	(3)	25	(9)
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	16	15	144	28
Entergy Arkansas [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	1.5		1.5
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	3.8		3.8		$ 2.7
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	3.4	4.8	29.5	9.4
Entergy Louisiana [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.7		0.7		0.3
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	4.8		4.8		4.2
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Current Liabilities [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability					0.3
Derivative, Collateral, Right to Reclaim Cash					0
Derivative Liability					0.3
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Noncurrent Liabilities
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability					1.3
Derivative, Collateral, Right to Reclaim Cash					0
Derivative Liability					1.3
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Deferred Debits And Other Assets [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.4		0.4		0.5
Entergy Louisiana [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	5		5		0.8
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	4.9		6.7	(1.3)
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	5.9	5.4	18.2	10.7
Entergy Mississippi [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.9		0.9		0.2
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	2		2		0.6
Entergy Mississippi [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Current Liabilities [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability					5
Derivative, Collateral, Right to Reclaim Cash					0
Derivative Liability					5
Entergy Mississippi [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	9.6		9.6
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	13.2	(2.5)	18.3	(7.7)
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.7	(0.4)	7.9	(0.5)
Entergy New Orleans [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	0.3		0.3		0.2
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.6		0.6		0.1
Entergy New Orleans [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Other Current Liabilities [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Liability, Fair Value, Gross Liability					0.3
Derivative, Collateral, Right to Reclaim Cash					0
Derivative Liability					0.3
Entergy New Orleans [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	0.1		0.1
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.1			(0.4)
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0.8	0.2	2	0.6
Entergy Texas [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Letters of Credit Outstanding, Amount	2.3		2.3		0.5
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member] | Prepayments And Other [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative Asset	3.8		3.8		$ 1.6
Entergy Texas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 4.8	$ 5.3	$ 82.7	$ 7.6

Risk Management and Fair Valu_7

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 529,616		$ 529,616		$ 1,630,248
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	33,000		33,000		42,000
Replacement Reserve Escrow	88,000		88,000		148,000
Equity Securities, FV-NI	53,000		53,000		1,533,000
Debt Securities	2,038,000		2,038,000		2,617,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	5,920,000		5,920,000		9,122,000
Issuance of Financial Transmission Rights	0	$ 0	0	$ 0
Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	12,000	23,000	12,000	23,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					7,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	3,148,000		3,148,000		3,103,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset					38,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	15,000		15,000		2,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	15,000		15,000		9,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	530,000		530,000		1,630,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	33,000		33,000		42,000
Replacement Reserve Escrow	88,000		88,000		148,000
Equity Securities, FV-NI	53,000		53,000		1,533,000
Debt Securities	686,000		686,000		919,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,405,000		1,405,000		4,273,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					6,000
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset					0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	15,000		15,000		1,000
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Replacement Reserve Escrow	0		0		0
Equity Securities, FV-NI	0		0		0
Debt Securities	1,352,000		1,352,000		1,698,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,352,000		1,352,000		1,699,000
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					1,000
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset					0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		1,000
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Replacement Reserve Escrow	0		0		0
Equity Securities, FV-NI	0		0		0
Debt Securities	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	15,000		15,000		47,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset					38,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	15,000		15,000		9,000
Entergy New Orleans [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	2,678		2,678		3,364
Replacement Reserve Escrow	38,800		38,800		83,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	42,200		42,200		86,500
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	400	(100)	400	(100)
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					300
Entergy New Orleans [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	100		100
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	600		600		100
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	2,700		2,700		3,400
Replacement Reserve Escrow	38,800		38,800		83,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	41,600		41,600		86,400
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					300
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	100		100
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Replacement Reserve Escrow	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0		0		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Replacement Reserve Escrow	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	600		600		100
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	600		600		100
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		7
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900		48,900		64,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	60,500		60,500		65,200
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	1,700	1,400	1,700	1,400
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					5,000
Entergy Mississippi [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	9,600		9,600
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	2,000		2,000		600
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Assets at fair value on a recurring basis
Replacement Reserve Escrow	48,900		48,900		64,600
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	58,500		58,500		64,600
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					5,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	9,600		9,600
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0		0		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]
Assets at fair value on a recurring basis
Replacement Reserve Escrow	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	2,000		2,000		600
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	2,000		2,000		600
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	206,643		206,643		726,717
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	3,700		3,700		2,700
Equity Securities, FV-NI	19,600		19,600		8,700
Debt Securities	697,500		697,500		632,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	2,206,000		2,206,000		2,528,900
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	4,100	13,200	4,100	13,200
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					1,600
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	1,268,400		1,268,400		1,153,100
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	5,400		5,400		1,300
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	4,800		4,800		4,200
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	206,600		206,600		726,700
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	3,700		3,700		2,700
Equity Securities, FV-NI	19,600		19,600		8,700
Debt Securities	213,200		213,200		172,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	448,100		448,100		911,300
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					300
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	5,000		5,000		800
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Equity Securities, FV-NI	0		0		0
Debt Securities	484,300		484,300		459,800
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	484,700		484,700		460,300
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					1,300
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	400		400		500
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Equity Securities, FV-NI	0		0		0
Debt Securities	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	4,800		4,800		4,200
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis					0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	4,800		4,800		4,200
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	16,244		16,244		168,020
Assets at fair value on a recurring basis
Equity Securities, FV-NI	12,700		12,700		1,300
Debt Securities	472,500		472,500		447,900
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,396,700		1,396,700		1,444,600
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	2,800	6,500	2,800	6,500
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	891,500		891,500		824,700
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,800		3,800		2,700
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	16,200		16,200		168,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	12,700		12,700		1,300
Debt Securities	99,200		99,200		98,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	128,100		128,100		267,500
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		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		0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0		0		0
Debt Securities	373,300		373,300		349,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	373,300		373,300		349,700
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		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		0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0		0		0
Debt Securities	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	3,800		3,800		2,700
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,800		3,800		2,700
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	0		0		248,570
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	26,278		26,278		36,233
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	30,100		30,100		286,400
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Liabilities at fair value on a recurring basis
Issuance of Financial Transmission Rights	2,700	$ 2,400	2,700	$ 2,400
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,800		3,800		1,600
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value					248,600
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	26,300		26,300		36,200
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	26,300		26,300		284,800
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value					0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	0		0		0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	0		0		0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value					0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	3,800		3,800		1,600
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset	3,800		3,800		1,600
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	119,083		119,083		216,383
Assets at fair value on a recurring basis
Equity Securities, FV-NI	6,000		6,000		3,800
Debt Securities	467,800		467,800		427,700
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	1,431,600		1,431,600		1,432,300
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	838,700		838,700		784,400
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	119,100		119,100		216,400
Assets at fair value on a recurring basis
Equity Securities, FV-NI	6,000		6,000		3,800
Debt Securities	207,300		207,300		177,300
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	332,400		332,400		397,500
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		0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0		0		0
Debt Securities	260,500		260,500		250,400
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	260,500		260,500		250,400
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		0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	0		0		0
Debt Securities	0		0		0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure	$ 0		$ 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 Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Issuance of Financial Transmission Rights	$ 0	$ 0	$ 0	$ 0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0	49,000	0	49,000	$ 0	$ 38,000	$ 85,000	$ 118,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0	16,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	(7,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)			2,000	60,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	0	(45,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements			(38,000)	(127,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings			(2,000)	(2,000)
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	15,000	22,000	15,000	22,000	4,000	9,000	4,000	10,000
Issuance of Financial Transmission Rights	12,000	23,000	12,000	23,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0	0	3,000	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	15,000	10,000	135,000	17,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(16,000)	(15,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements			(144,000)	(28,000)
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	3,800	6,100	3,800	6,100	1,400	2,700	1,100	3,300
Issuance of Financial Transmission Rights	2,800	6,500	2,800	6,500
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				5,700
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	3,000	3,300	27,800
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(3,400)	(4,800)	(29,500)	(9,400)
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	4,800	12,500	4,800	12,500	1,200	4,200	1,900	4,500
Issuance of Financial Transmission Rights	4,100	13,200	4,100	13,200
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				5,500
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	5,400	2,800	14,700
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(5,900)	(5,400)	(18,200)	(10,700)
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	2,100	1,100	2,100	1,100	300	600	300	800
Issuance of Financial Transmission Rights	1,700	1,400	1,700	1,400
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	800		7,700
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements				(500)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	700	400	7,900
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(1,600)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(1,000)
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	600		600		100	100	0	300
Issuance of Financial Transmission Rights	400	(100)	400	(100)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				200
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	900	100	2,100
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	(800)	200	2,000	600
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value		(200)		(200)
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	3,800	2,600	3,800	2,600	$ 500	$ 1,600	$ 300	$ 900
Issuance of Financial Transmission Rights	2,700	2,400	2,700	2,400
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				6,900
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	5,400	5,200	82,200
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	$ (4,800)	$ (5,300)	$ (82,700)	$ (7,600)

Risk Management and Fair Valu_9

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) - Gas Hedge Contracts [Member]	6 Months Ended
	Jun. 30, 2021
Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	2 years 9 months
Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	9 months
Entergy New Orleans [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	9 months

Decommissioning Trust Funds (Na

Decommissioning Trust Funds (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020	May 28, 2021
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	$ (27)	$ 10,812	$ (25,608)	$ 19,555
Amortized cost of debt securities	$ 1,954,000		$ 1,954,000		$ 2,423,000
Average coupon rate of debt securities	2.82%		2.82%
Average duration of debt securities, years			6 years 11 months 8 days
Average maturity of debt securities, years			10 years 9 months
Proceeds from the dispositions of debt securities	$ 273,000	276,000	$ 797,000	676,000
Gains from dispositions of debt securities, gross	6,000	15,000	17,000	29,000
Losses from dispositions of debt securities, gross	1,000	1,000	12,000	4,000
Debt Securities, Available-for-sale, Allowance for Credit Loss	200		200		100
Equity Securities, FV-NI, Unrealized Gain	228,000		389,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			5,000		31,000
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 458,500		$ 458,500		420,400
Average coupon rate of debt securities	2.45%		2.45%
Average duration of debt securities, years			6 years 10 months 17 days
Average maturity of debt securities, years			8 years 1 month 20 days
Proceeds from the dispositions of debt securities	$ 12,300	17,700	$ 26,100	66,400
Gains from dispositions of debt securities, gross	700	1,300	1,600	5,800
Losses from dispositions of debt securities, gross	100	100	100	200
Equity Securities, FV-NI, Unrealized Gain	64,300		109,900
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 661,000		$ 661,000		581,400
Average coupon rate of debt securities	3.44%		3.44%
Average duration of debt securities, years			6 years 9 months 7 days
Average maturity of debt securities, years			12 years 3 months 25 days
Proceeds from the dispositions of debt securities	$ 62,500	34,100	$ 170,900	101,500
Gains from dispositions of debt securities, gross	1,500	2,000	4,800	4,900
Losses from dispositions of debt securities, gross	100	100	$ 3,300	700
Percentage Interest in River Bend			30.00%
Equity Securities, FV-NI, Unrealized Gain	92,900		$ 157,400
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 450,900		$ 450,900		398,400
Average coupon rate of debt securities	2.43%		2.43%
Average duration of debt securities, years			7 years 3 months 7 days
Average maturity of debt securities, years			10 years 8 months 4 days
Proceeds from the dispositions of debt securities	$ 101,600	73,600	$ 175,700	165,600
Gains from dispositions of debt securities, gross	1,900	5,400	3,100	7,000
Losses from dispositions of debt securities, gross	200	$ 200	1,800	$ 400
Equity Securities, FV-NI, Unrealized Gain	60,600		103,300
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					991,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					631,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					794,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 564,000		$ 564,000		$ 554,000
Entergy Wholesale Commodities [Member] | Indian Point Energy Center
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value						$ 2,387,000

Decommissioning Trust Funds (Se

Decommissioning Trust Funds (Securities Held) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 2,038	$ 2,617
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	92	197
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	8	3
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	472.5	447.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	16.7	27.7
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.7	0.3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	697.5	632.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	38.4	51.3
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	1.9	0.5
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	467.8	427.7
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	19.4	30
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 2.5	$ 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	Jun. 30, 2021	Dec. 31, 2020
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 482	$ 187
More than 12 months Fair Value	3	2
Total Fair Value	485	189
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	8	3
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	8	3
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	127.7	29.9
More than 12 months Fair Value	2	0
Total Fair Value	129.7	29.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2.7	0.3
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2.7	0.3
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	124.4	36.4
More than 12 months Fair Value	0.7	0.8
Total Fair Value	125.1	37.2
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	1.9	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	1.9	0.5
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	149.1	28.9
More than 12 months Fair Value	0.1	0
Total Fair Value	149.2	28.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2.5	0.8
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 2.5	$ 0.8

Decommissioning Trust Funds (Fa

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Fair value of debt securities by contractual maturities
1 year - 5 years	$ 455	$ 672
5 years - 10 years	663	852
10 years - 15 years	335	377
15 years - 20 years	117	144
20 years+	468	576
Total	2,038	2,617
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0
Debt Securities, Available-for-Sale, Maturity, Allocated and Single Maturity Date, within One Year, Negative Fair Value		(4)
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	93.6	113.1
5 years - 10 years	191.6	189.8
10 years - 15 years	121.5	81.4
15 years - 20 years	28.8	28.5
20 years+	37	35.1
Total	472.5	447.9
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0	0
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	122.7	117
5 years - 10 years	188.4	159.4
10 years - 15 years	103.5	101.2
15 years - 20 years	74.3	66.9
20 years+	208.6	187.7
Total	697.5	632.2
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	0	0
System Energy [Member]
Fair value of debt securities by contractual maturities
1 year - 5 years	144	134.7
5 years - 10 years	147.3	141.5
10 years - 15 years	46.3	31.5
15 years - 20 years	2.8	5.3
20 years+	127.4	115.8
Total	467.8	427.7
Debt Securities, Available-for-sale, Maturity, Allocated and Single Maturity Date, within One Year, Fair Value	$ 0
Debt Securities, Available-for-Sale, Maturity, Allocated and Single Maturity Date, within One Year, Negative Fair Value		$ (1.1)

Income Taxes Income Taxes (Redu

Income Taxes Income Taxes (Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 14	$ 15	$ 54	$ 45
Valuation Allowance - Reduction	9
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0		8	12
Increase in regulatory liability due to return of unprotected excess accumulated deferred income taxes		(1)
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	8	8	15	16
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	2	0	5
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	6	6	13	12
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 0	$ 0	$ 18	$ 0

Property, Plant, And Equipment

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Construction expenditures in accounts payable	$ 254	$ 745
Entergy Arkansas [Member]
Construction expenditures in accounts payable	35.3	59.7
Entergy Louisiana [Member]
Construction expenditures in accounts payable	95.7	460.5
Entergy Mississippi [Member]
Construction expenditures in accounts payable	26.3	31.4
Entergy New Orleans [Member]
Construction expenditures in accounts payable	3.8	9.2
Entergy Texas [Member]
Construction expenditures in accounts payable	45	116.8
System Energy [Member]
Construction expenditures in accounts payable	$ 16.7	$ 17.7

Variable Interest Entities (Nar

Variable Interest Entities (Narrative) (Details) - System Energy [Member] - Grand Gulf [Member] - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	11.50%
Payments on lease, including interest	$ 8.6	$ 8.6

Revenue Recognition (Disaggrega

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 2,822,070	$ 2,412,788	$ 5,666,907	$ 4,839,967
Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	550,274	491,767	1,133,660	973,679
Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,267,598	1,011,652	2,375,242	1,942,299
Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	349,040	297,954	685,659	591,876
Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	178,740	147,343	348,075	296,645
Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	430,434	372,194	910,654	711,530
Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,641,375	2,190,557	5,179,794	4,241,196
Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	550,274	491,767	1,133,660	973,679
Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,254,579	1,001,601	2,334,242	1,914,142
Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	349,040	297,954	685,659	591,876
Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	159,761	134,899	298,909	258,330
Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	430,434	372,194	910,654	711,530
Natural Gas, US Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	31,998	22,495	90,166	66,471
Natural Gas, US Regulated [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Natural Gas, US Regulated [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	13,019	10,051	41,000	28,157
Natural Gas, US Regulated [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Natural Gas, US Regulated [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,979	12,444	49,166	38,315
Natural Gas, US Regulated [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	148,697	199,736	396,947	532,300
Residential [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	855,586	790,869	1,822,441	1,588,897
Residential [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	171,103	171,171	408,284	390,859
Residential [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	340,643	301,105	676,403	560,965
Residential [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	117,461	112,361	265,097	239,463
Residential [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	60,186	53,420	126,613	104,319
Residential [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	166,193	152,811	346,044	293,291
Commercial [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	628,703	526,121	1,201,380	1,065,061
Commercial [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	111,187	106,104	217,603	217,349
Commercial [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	262,351	209,119	487,000	411,365
Commercial [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	101,644	89,594	199,580	186,392
Commercial [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	51,092	36,401	98,891	81,905
Commercial [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	102,429	84,904	198,306	168,050
Industrial [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	756,959	576,203	1,354,610	1,133,718
Industrial [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	114,284	106,254	217,696	207,342
Industrial [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	475,185	335,201	822,194	657,542
Industrial [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	36,545	35,874	70,524	72,264
Industrial [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	8,028	3,066	14,817	10,413
Industrial [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	122,917	95,809	229,379	186,157
Governmental [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	61,612	46,959	118,409	99,541
Governmental [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4,536	4,344	8,791	8,374
Governmental [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	21,547	16,781	40,163	33,535
Governmental [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	10,873	9,798	21,416	20,125
Governmental [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,312	10,475	34,692	26,326
Governmental [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,344	5,560	13,347	11,180
Billed Retail [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,302,860	1,940,152	4,496,840	3,887,217
Billed Retail [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	401,110	387,873	852,374	823,924
Billed Retail [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,099,726	862,206	2,025,760	1,663,407
Billed Retail [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	266,523	247,627	556,617	518,244
Billed Retail [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	137,618	103,362	275,013	222,963
Billed Retail [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	397,883	339,084	787,076	658,678
Sales for Resale [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	119,130	52,761	324,205	106,487
Sales for Resale [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	69,750	36,956	179,834	78,096
Sales for Resale [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	74,343	82,698	154,771	161,228
Sales for Resale [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	44,050	18,426	84,360	32,848
Sales for Resale [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	12,810	8,018	17,506	18,188
Sales for Resale [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	19,542	13,187	93,615	21,815
Non-Customer [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	32,307	28,923	91,410	28,605
Non-Customer [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6,205	3,401	8,661	6,525
Non-Customer [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	24,765	3,593	54,057	4,394
Non-Customer [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,077	2,508	4,341	4,948
Non-Customer [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(177)	19,520	239	12,416
Non-Customer [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(568)	(116)	(1,143)	295
Non-Customer [Member] | Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,017	24,016	18,153	140,577
Other Electric [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	187,078	168,721	267,339	218,887
Other Electric [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	73,209	63,537	92,791	65,134
Other Electric [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	55,745	53,104	99,654	85,113
Other Electric [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	36,390	29,393	40,341	35,836
Other Electric [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9,510	3,999	6,151	4,763
Other Electric [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	13,577	20,039	31,106	30,742
Revenues from customers [Member] | Electricity [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,609,068	2,161,634	5,088,384	4,212,591
Revenues from customers [Member] | Electricity [Member] | Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	544,069	488,366	1,124,999	967,154
Revenues from customers [Member] | Electricity [Member] | Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,229,814	998,008	2,280,185	1,909,748
Revenues from customers [Member] | Electricity [Member] | Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	346,963	295,446	681,318	586,928
Revenues from customers [Member] | Electricity [Member] | Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	159,938	115,379	298,670	245,914
Revenues from customers [Member] | Electricity [Member] | Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	431,002	372,310	911,797	711,235
Competitive Business Sales [Member] | Competitive Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 146,680	$ 175,720	$ 378,794	$ 391,723

Revenue Recognition (Allowance

Revenue Recognition (Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	$ 109.1	$ 43.2	$ 117.7	$ 7.4
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	25.9	38.4
Accounts Receivable, Allowance for Credit Loss, Writeoff	(39.5)	(8.6)
Accounts Receivable, Allowance for Credit Loss, Recovery	5	6
Entergy Arkansas [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	22.4	7.3	18.3	1.2
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	5.5	6.3
Accounts Receivable, Allowance for Credit Loss, Writeoff	(2.8)	(1.8)
Accounts Receivable, Allowance for Credit Loss, Recovery	1.4	1.6
Entergy Louisiana [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	39.8	14.5	45.7	1.9
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	11.7	14.1
Accounts Receivable, Allowance for Credit Loss, Writeoff	(19.5)	(3.5)
Accounts Receivable, Allowance for Credit Loss, Recovery	1.9	2
Entergy Mississippi [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	13.6	7.2	19.5	0.6
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	1.7	7
Accounts Receivable, Allowance for Credit Loss, Writeoff	(8.8)	(1.2)
Accounts Receivable, Allowance for Credit Loss, Recovery	1.2	0.8
Entergy New Orleans [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	21.1	8.4	17.4	3.2
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	4.6	5.5
Accounts Receivable, Allowance for Credit Loss, Writeoff	(1.1)	(1)
Accounts Receivable, Allowance for Credit Loss, Recovery	0.2	0.7
Entergy Texas [Member]
Disaggregation of Revenue [Line Items]
Allowance for Doubtful Other Receivables, Current	12.2	5.8	$ 16.8	$ 0.5
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	2.4	5.5
Accounts Receivable, Allowance for Credit Loss, Writeoff	(7.3)	(1.1)
Accounts Receivable, Allowance for Credit Loss, Recovery	$ 0.3	$ 0.9

Business Combinations (Narrativ

Business Combinations (Narrative) (Details) $ in Thousands	1 Months Ended			6 Months Ended
	Jun. 30, 2021USD ($)MW	May 31, 2021USD ($)	Apr. 30, 2019	Jun. 30, 2021USD ($)	Jun. 30, 2020USD ($)	May 28, 2021USD ($)
Proceeds from Sale of Productive Assets				$ 22,421	$ 0
Payments to Acquire Productive Assets				36,534	24,633
Entergy Texas [Member]
Proceeds from Sale of Productive Assets				67,920	0
Payments to Acquire Productive Assets				$ 36,534	$ 4,931
Hardin County Peaking Facility | Entergy Texas [Member]
Capacity Of Power Plant Unit | MW	147
Payments to Acquire Productive Assets	$ 36,700
Montgomery County Power Station | Entergy Texas [Member]
Proceeds from Sale of Productive Assets	$ 67,900
Percentage of Undivided Ownership Interest	7.56%
Indian Point Energy Center | Entergy Wholesale Commodities [Member]
Percentage of Undivided Ownership Interest			100.00%
Gain (Loss) on Disposition of Assets		$ 340,000
Gain (Loss) on Disposition of Assets (Net-Of-Tax)		$ 268,000
Decommissioning Fund Investments, Fair Value						$ 2,387,000
Asset Retirement Obligation						$ 1,996,000

Uncategorized Items - etr-20210

Label	Element	Value
AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ (446,920,000)
Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,700,000
Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	6,564,436,000
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	9,257,190,000
Subsidiaries Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	35,000,000
Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,154,150,000)
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] | AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
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] | Additional Paid-in Capital [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 [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